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Outdoor Lighting 2024-01-012024-12-31 C000199 D180-O'HARE FIELD, Distribution, Unattended 2024-01-012024-12-31 C000199 555-GLEN ELLYN, Distribution, Unattended 2024-01-012024-12-31 C000199 12002 LOMBARD, ITASCA, ST, 2156 ACSR 2024-01-012024-12-31 C000199 Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock 2024-01-012024-12-31 C000199 PJM AE1-070 Elwood 345 kV Faci921 2024-01-012024-12-31 C000199 ferc:OperatingReserveSupplementMember 2024-01-012024-12-31 C000199 13805 SILVER LAKE - 4, SW TIE L-18513, WH, 1113 ACSR 2024-01-012024-12-31 C000199 0703 STATE LINE, HEGEWISCH, ST, 1113 ACSR 2024-01-012024-12-31 C000199 S25-GRAND RAPIDS, Distribution, Unattended 2024-01-012024-12-31 C000199 Lakeview - 1141 W. 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1, ELECTRIC JUNCTION, ST, 2156 ACSR, 2338 ACAR 2024-01-012024-12-31 C000199 Funds for Utility Job Training Program (FEJA) 2024-12-31 C000199 Other Accounts (Specify, details in footnote): 2024-01-012024-12-31 C000199 TSS101 Itasca 138kV Cap Bankferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 Upgrade 138kV Line 0108ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 D217-CICERO, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-535 Facilities Study561.7 2024-01-012024-12-31 C000199 Distribution Service Costs 2024-01-012024-12-31 C000199 Director's fees and expenses 2024-01-012024-12-31 C000199 Project Post - ESS E 535 - 1ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 Z310-DREXEL, Distribution, Unattended 2024-01-012024-12-31 C000199 Prime Data Centerferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-070 Facilities Study408.1 2024-01-012024-12-31 C000199 D175-SCHILLER PARK-2, Distribution, Unattended 2024-12-31 C000199 115-BEDFORD PARK-1, Transmission, Unattended 2024-12-31 C000199 ferc:JanuaryMember 0 2024-01-012024-12-31 C000199 122-BELVIDERE-2, Distribution, Unattended 2024-12-31 C000199 B29-BYRON, Distribution, Unattended 2024-01-012024-12-31 C000199 687-NORWOOD PARK, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember AF2-352 PJM Facilities Study926 2024-01-012024-12-31 C000199 TSS177 Burnham TR84 Replacemenferc:ElectricUtilityMember 2024-12-31 C000199 1606 WAUKEGAN - 2, HIGHLAND PARK, WP, 1113 ACSR 2024-01-012024-12-31 C000199 11418 ADDISON RIVER, DIVERSEY, UG, 2000 kcmil HPFF 2024-01-012024-12-31 C000199 Microsoft CHI07 Data Centerferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 4P223700-DCE27 Arlington Hts’ 2024-01-012024-12-31 C000199 15518 NELSON - 3, GARDEN PLAIN, WH, 266.8 ACSR 2024-01-012024-12-31 C000199 S39-MINONK, Distribution, Unattended 2024-01-012024-12-31 C000199 J46-KAVANAUGH, Distribution, Unattended 2024-01-012024-12-31 C000199 K50-NORTH MOMENCE, Distribution, Unattended 2024-01-012024-12-31 C000199 J33-WASH ST (JOLIET), Distribution, Unattended 2024-12-31 C000199 ferc:GenerationStudiesMember PJM AE2-261 Facilities Study408.1 2024-01-012024-12-31 C000199 163-ROSCOE BERT-2, Distribution, Unattended 2024-12-31 C000199 13510 ELMHURST - 3, FRANKLIN PARK, WP, 1113 ACSR 2024-01-012024-12-31 C000199 Z310-DREXEL, Distribution, Unattended 2024-12-31 C000199 98105 CRESCENT RIDGE - 1, CORBIN (AMEREN), SP, 477,1113,2-556.5 ACSR 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-296 Facilities Study408.1 2024-01-012024-12-31 C000199 103-LISLE-2, Distribution, Unattended 2024-12-31 C000199 Chicago Infrastructure Maintenance Fee, Other Taxes, IL, 2024ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 ferc:ElectricUtilityMember 4% 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-183- Nelson Lee County408.1 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-030 Facility Study921 2024-01-012024-12-31 C000199 A49-WAUKEGAN, Distribution, Unattended 2024-01-012024-12-31 C000199 Project Post - ESS E 535ferc:ElectricUtilityMember 2024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-363 Cherry Valley-Glid921 2024-01-012024-12-31 C000199 2019 REACTS STA22-STA16 BBFferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 Long Term Performance Plan - 1ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 8605 DAVIS CREEK - 2, BRADLEY, WP, 1113 ACSR 2024-01-012024-12-31 C000199 Various complaint and petition matters 2024-12-31 C000199 205-WHEELING, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-298 Facilities Study921 2024-01-012024-12-31 C000199 PJM AE1-070 Elwood 345 kV Faci926 2024-01-012024-12-31 C000199 8223 CROSBY - 2, ROCKWELL, SP, 1113 ACSR 2024-01-012024-12-31 C000199 PJM AF2-034 Facilities Study408.1 2024-01-012024-12-31 C000199 11614 GOODINGS GROVE - 2, WILTON CENTER, SP, 2338 ACAR, 2156 ACSR 2024-01-012024-12-31 C000199 H43-AMBOY (GREEN RIVER), Distribution, Unattended 2024-01-012024-12-31 C000199 5104 TAP - 2, ARGONNE LABS, WP, 1113 ACSR 2024-01-012024-12-31 C000199 B42-PEARL CITY, Distribution, Unattended 2024-01-012024-12-31 C000199 B14-HARVARD, Distribution, Unattended 2024-12-31 C000199 J38-MESSENGER WOODS, Distribution, Unattended 2024-01-012024-12-31 C000199 TSS184 Elk Grove-345kV TR 82ferc:ElectricUtilityMember 2024-12-31 C000199 2024-12-31 C000199 D255-FORESTVIEW, Distribution, Unattended 2024-12-31 C000199 8604 DAVIS CREEK - 1, BRADLEY, SP, 1113, T2-556.5, ACSR 2024-01-012024-12-31 C000199 268-ARLINGTON, Distribution, Unattended 2024-12-31 C000199 Decommissioning the Regulatory Agreement Units 2024-01-012024-12-31 C000199 1317 CRAWFORD, FISK, UG, 2500 HPFF 2024-01-012024-12-31 C000199 110-DEVON, Distribution, Unattended 2024-01-012024-12-31 C000199 15515 NELSON, SCHAUFF ROAD, SP, 2-556.5, 1590 ACSR 2024-01-012024-12-31 C000199 PJM Interconnection, LLC, OS, PJM-1 2024-01-012024-12-31 C000199 1608 WAUKEGAN - 2, LIBERTYVILLE, SP, 1113 ACSR 2024-01-012024-12-31 C000199 S40-LODEMIA, Distribution, Unattended 2024-01-012024-12-31 C000199 B43-STOCKTON, Distribution, Unattended 2024-01-012024-12-31 C000199 TSS 181 Compass Data Centerferc:ElectricUtilityMember 2024-12-31 C000199 6P240007 TSS149 12kVferc:ElectricUtilityMember 2024-12-31 C000199 82-CROSBY, Distribution, Unattended 2024-12-31 C000199 A12-LIBERTYVILLE, Distribution, Unattended 2024-01-012024-12-31 C000199 W38-DOWNERS GROVE TW, Distribution, Unattended 2024-12-31 C000199 121-FREEPORT-1, Distribution, Unattended 2024-12-31 C000199 W64-TRI STATE-1, Distribution, Unattended 2024-01-012024-12-31 C000199 592-OSWEGO, Distribution, Unattended 2024-12-31 C000199 PJM AF2-319 Facilities Study926 2024-01-012024-12-31 C000199 Apollo Phase 2 W/O WPT SWferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 ferc:Quarter3Member 0 2024-01-012024-12-31 C000199 0108 TAP, SW TIE L-6102, WP, 477 ACSR 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-350921 2024-01-012024-12-31 C000199 6607 EAST FRANKFORT - 1, CRETE E.C., SP, 2156 ACSR 2024-01-012024-12-31 C000199 139-MENDOTA, Distribution, Unattended 2024-12-31 C000199 E12-PALATINE, Distribution, Unattended 2024-01-012024-12-31 C000199 B19-BELVIDERE-1, Distribution, Unattended 2024-12-31 C000199 11702 PROSPECT HTS - 3, DES PLAINES 46, WH, 1113 ACSR 2024-01-012024-12-31 C000199 18513 TOLLWAY, SW TIE L-13805, SP, 1277.2 ACAR / 111 2024-01-012024-12-31 C000199 1802 WILL COUNTY - 2, ARGONNE, SP, 1113 ACSR 2024-01-012024-12-31 C000199 B57-UNION, Distribution, Unattended 2024-12-31 C000199 12015 LOMBARD - 1, ITASCA, ST, 1113 ACSR 2024-01-012024-12-31 C000199 1802 WILL COUNTY - 3, ARGONNE, WP, 1113 ACSR 2024-01-012024-12-31 C000199 Real Estate, Property Tax, IL, 2023 2023-12-31 C000199 Long Term receivable from the MBA Plan 2023-12-31 C000199 Chicago Transaction Tax, Other Taxes, IL, 2024 2023-12-31 C000199 G113-HARVEY, Distribution, Unattended 2024-01-012024-12-31 C000199 71-HIGGINS, Distribution, Unattended 2024-01-012024-12-31 C000199 PJM AE2-321 Facilities Study926 2024-01-012024-12-31 C000199 H14-SANDWICH, Distribution, Unattended 2024-01-012024-12-31 C000199 D47-BROADVIEW-1, Distribution, Unattended 2024-12-31 C000199 G909-DOLTON-1, Distribution, Unattended 2024-01-012024-12-31 C000199 129, 3.000% 2024-01-012024-12-31 C000199 1-LASALLE, Transmission, Attended 2024-12-31 C000199 Municipal Utility Tax, Other Taxes, IL, 2024ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 0722 STATE LINE, BURNHAM, ST, 2338 ACAR 2024-01-012024-12-31 C000199 Unemployment Insurance (SUTA), Unemployment Tax, IL, 2023 2023-12-31 C000199 C43-EVANSTON, Distribution, Unattended 2024-01-012024-12-31 C000199 PJM AG1-512926 2024-01-012024-12-31 C000199 D242-BRIDGEVIEW, Distribution, Unattended 2024-01-012024-12-31 C000199 4621 DESPLAINES - 1, GOLF MILL, ST, 2156 ACSR 2024-01-012024-12-31 C000199 oneMDS Mobile Dispatch SW RL4 2024-01-012024-12-31 C000199 W336-MILTON TWP, Distribution, Unattended 2024-01-012024-12-31 C000199 L1863/L1864/L1865 Relocationferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 D87-LEYDEN TWP-1, Distribution, Unattended 2024-12-31 C000199 Use Tax, Sales And Use Tax, IL, 2024ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 4608 DESPLAINES 46 - 3, DESPLAINES 198, SP, 1113 ACSR 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-200 Facilities Study926 2024-01-012024-12-31 C000199 G126-DOLTON, Distribution, Unattended 2024-01-012024-12-31 C000199 556-BERWYN-2, Distribution, Unattended 2024-12-31 C000199 PJM AG1-434 Facilities Study921 2024-01-012024-12-31 C000199 0ferc:UnappriatedUndistributedSubsidiaryEarningsMember 2024-12-31 C000199 PJM AG1-435 Facilities Study408.1 2024-01-012024-12-31 C000199 462-DWIGHT, Distribution, Unattended 2024-01-012024-12-31 C000199 Docket No.  22-0067  Performance Metrics 2024-01-012024-12-31 C000199 141-PLEASANT VALLEY, Transmission, Unattended 2024-12-31 C000199 Computer Equipment 2024-01-012024-12-31 C000199 249-WILMETTE-2, Distribution, Unattended 2024-12-31 C000199 X305-SEMINARY, Distribution, Unattended 2024-12-31 C000199 11614 TAP, BLUE ISLAND, ST, 2338 ACAR 2024-01-012024-12-31 C000199 C77-SKOKIE, Distribution, Unattended 2024-12-31 C000199 L17401 Leak Repairferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 853-62ND STREET, Distribution, Unattended 2024-01-012024-12-31 C000199 AE1-114 PJM Facilities Study926 2024-01-012024-12-31 C000199 6P230800 - 4:12 conversionsferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember AF2-252 PJM Facilities Study921 2024-01-012024-12-31 C000199 Federal Income Tax, Income Tax, Fed, 2024 2023-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-031 Facility Study408.1 2024-01-012024-12-31 C000199 Other Projectsferc:ElectricUtilityMember 2024-12-31 C000199 E26-LAKE IN THE HILLS, Distribution, Unattended 2024-01-012024-12-31 C000199 8605 TAP - 1, CSL BEHRING, SP, 2-556.5,1113 ACSR 2024-01-012024-12-31 C000199 D69-BROADVIEW-1, Distribution, Unattended 2024-12-31 C000199 J58-MANHATTAN, Distribution, Unattended 2024-01-012024-12-31 C000199 3P240200 : New Fdr Z1412ferc:ElectricUtilityMember 2024-12-31 C000199 S211 - Customer Target BESSferc:ElectricUtilityMember 2024-12-31 C000199 D24-WESTERN SPRINGS, Distribution, Unattended 2024-12-31 C000199 GDVA Implementation SWferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 Long Term receivable from Constellation Energy Generation, LLC (formerly Exelon Generation Company, LLC) (SFAS 143, Regulatory Liability offset) 2024-01-012024-12-31 C000199 Pine TUG 138kV L10108-Tferc:ElectricUtilityMember 2024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-462 Facilities Study921 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-441 Facilities Study408.1 2024-01-012024-12-31 C000199 B40-KETCHUM, Distribution, Unattended 2024-12-31 C000199 Long Term receivable from the MBA Plan 2024-12-31 C000199 C21-OPTIMA, Distribution, Unattended 2024-12-31 C000199 73-CHICAGO HEIGHTS, Distribution, Unattended 2024-12-31 C000199 L19414 S. Pecatonic break 2024-01-012024-12-31 C000199 REACTS 1C224302 TSS30-TSS30-1 2024-01-012024-12-31 C000199 Real Estate, Property Tax, IL, 2024 2023-12-31 C000199 557-BUTTERFIELD, Distribution, Unattended 2024-01-012024-12-31 C000199 Chicago Infrastructure Maintenance Fee, Other Taxes, IL, 2024 2023-12-31 C000199 S20-RUTLAND, Distribution, Unattended 2024-01-012024-12-31 C000199 3705 NATOMA, FRANKLIN PARK, UG, 2000 kcmil HPFF 2024-01-012024-12-31 C000199 Vehicle License, Other License And Fees Tax, IL, 2023 2024-12-31 C000199 17908 BURNHAM, BLOOM, ST, 2156 ACSR, 2338 ACAR 2024-01-012024-12-31 C000199 L17401 Leak Repair 2024-01-012024-12-31 C000199 561-BOLINGBROOK, Distribution, Unattended 2024-01-012024-12-31 C000199 PJM AF2-142 Facilities Study408.1 2024-01-012024-12-31 C000199 PJM AF1-253 Facilities Study921 2024-01-012024-12-31 C000199 592-OSWEGO, Distribution, Unattended 2024-01-012024-12-31 C000199 W148-AURORA TWP, Distribution, Unattended 2024-01-012024-12-31 C000199 7713 MAZON - 2, CORBIN (AMEREN), SP, 1113 ACSR 2024-01-012024-12-31 C000199 ferc:OtherLicenseAndFeesTaxMember 2024-12-31 C000199 D267-LEYDEN TWP, Distribution, Unattended 2024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-128 Crescent Ridge-Cor561.7 2024-01-012024-12-31 C000199 85-SKOKIE-1, Distribution, Unattended 2024-12-31 C000199 ADMS - 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contracts 2024-12-31 C000199 B44-WARREN, Distribution, Unattended 2024-01-012024-12-31 C000199 3709 NATOMA, OAK PARK, UG, 2000 kcmil HPFF 2024-01-012024-12-31 C000199 H57-LEE, Distribution, Unattended 2024-12-31 C000199 PJM AG1-512408.1 2024-01-012024-12-31 C000199 ferc:UnemploymentTaxMemberferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 2020 REACTS TSS193-TSS193 DFRferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 2020 REACTS TSS60-TDC461-2 DFRferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 580-DOWNERS GROVE, Distribution, Unattended 2024-12-31 C000199 PowerPlan Upgrade SWferc:ElectricUtilityMember 2024-12-31 C000199 ScheduleAllowanceInventoryAbstract 2024-01-012024-12-31 C000199 894-HARPER, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GeneralPlantMemberferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 106-MONTGOMERY-2, Distribution, Unattended 2024-12-31 C000199 W35-UDINA, Distribution, Unattended 2024-12-31 C000199 4% 2024-01-012024-12-31 C000199 F111-PARK FOREST, Distribution, Unattended 2024-01-012024-12-31 C000199 7612 BLUE ISLAND - 2, WILDWOOD, SP, 900 ACSR 2024-01-012024-12-31 C000199 C33-NILES-1, Distribution, Unattended 2024-01-012024-12-31 C000199 11103 ELECTRIC JUNCTION - 1, AURORA E.C., SP, 1113 ACSR 2024-01-012024-12-31 C000199 312-STEWARD, Distribution, Unattended 2024-12-31 C000199 PJM AG1-127 Facilities Study921 2024-01-012024-12-31 C000199 Long-Term Receivable Related to the FERC 494 Refund 2024-01-012024-12-31 C000199 Chicago Transaction Tax, Other Taxes, IL, 2024ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 Long Term Performance Plan - 3 2024-01-012024-12-31 C000199 20150519-5140, 42143, ER09-1145-000 2024-01-012024-12-31 C000199 Attachment H-13A of PJM of OATT - Revised, Docket No. ER14-1203-000 2024-01-012024-12-31 C000199 2224 ZION - 2, LIBERTYVILLE, SP, 2338 ACAR 2024-01-012024-12-31 C000199 11120 ELECTRIC JUNCTION - 1, LOMBARD, ST, 2156 ACSR 2024-01-012024-12-31 C000199 15503 NELSON - 1, CORDOVA, ST, 2-1033.5 ACSS/TW, 2024-01-012024-12-31 C000199 107, 6.450% 2024-01-012024-12-31 C000199 814-DAMEN, Distribution, Unattended 2024-01-012024-12-31 C000199 D34-BERWYN, Distribution, Unattended 2024-01-012024-12-31 C000199 W48-HINSDALE, Distribution, Unattended 2024-01-012024-12-31 C000199 D111-ELMWOOD PARK, Distribution, Unattended 2024-01-012024-12-31 C000199 Iron Mountain TSS46 DesPlainesferc:ElectricUtilityMember 2024-12-31 C000199 AF2-225 McLean 345kV921 2024-01-012024-12-31 C000199 Eakin Creek TSSferc:LandAndRightsMember 2024-12-31 C000199 1607 TAP, ROUND LAKE, SP, 477 ACSR 2024-01-012024-12-31 C000199 Passenger Cars 2024-01-012024-12-31 C000199 84-ROSEHILL, Distribution, Unattended 2024-01-012024-12-31 C000199 12411 MARYLAND - 3, DIXON, WH, 3/0 CO 2024-01-012024-12-31 C000199 AEP Energy Partners, Inc. , OS, 2024-01-012024-12-31 C000199 Transmission Costs - Under Recovery 2024-12-31 C000199 Docket No. 23-0055 Verified Petition for Approval of a Multi-Year Rate Plan - amortized over 4 years (2024-2027) 2024-01-012024-12-31 C000199 C73-TECHNY-2, Distribution, Unattended 2024-12-31 C000199 2219 ZION, WAUKEGAN, SP, 2156 ACSR 2024-01-012024-12-31 C000199 88-SKOKIE-1, Transmission, Unattended 2024-12-31 C000199 PJM AF1-318 Facilities Study921 2024-01-012024-12-31 C000199 11301WATERMAN - 1, SANDWICH, SP, 1113 ACSR 2024-01-012024-12-31 C000199 Z312-EXCHANGE, Distribution, Unattended 2024-01-012024-12-31 C000199 Uncollectible Accounts Expense - Under Recovery 2024-12-31 C000199 LAGRANGE, , 2024-01-012024-12-31 C000199 182-MINONK, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-030 Facility Study561.7 2024-01-012024-12-31 C000199 H10-PRARIEVILLE, Distribution, Unattended 2024-12-31 C000199 19601 KATYDID - 2, GOODINGS GROVE, ST, 2-1277 ACAR, 2156 2024-01-012024-12-31 C000199 UA HQ Data Center TSS184ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 11411 NORTHWEST, DEVON, UG, 2000 kcmil HPFF 2024-01-012024-12-31 C000199 B37-FORRESTON, Distribution, Unattended 2024-01-012024-12-31 C000199 39-PORTAGE, Distribution, Unattended 2024-12-31 C000199 L2105 Line Rebuildferc:ElectricUtilityMember 2024-12-31 C000199 W28-SUNSET PARK, Distribution, Unattended 2024-01-012024-12-31 C000199 76-BLUE ISLAND-2, Distribution, Unattended 2024-12-31 C000199 116, 4.700% 2024-01-012024-12-31 C000199 Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock 2024-01-012024-12-31 C000199 AE2-107 Haumesser Rd PJM Study408.1 2024-01-012024-12-31 C000199 PJM AF2-366 Facilities Study408.1 2024-01-012024-12-31 C000199 Z306-NARRAGANSETT, Distribution, Unattended 2024-12-31 C000199 Unemployment Insurance (FUTA), Unemployment Tax, Fed, 2023 2023-12-31 C000199 11106 ELECTRIC JUNCTION - 2, WATERMAN, SP, 2-556.5 ACSR 2024-01-012024-12-31 C000199 362293 :FR-S ELGIN S MCLEAN BLferc:ElectricUtilityMember 2024-12-31 C000199 Unemployment Insurance (FUTA), Unemployment Tax, Fed, 2024 2024-01-012024-12-31 C000199 AF1-048 Belvidere Morengo408.1 2024-01-012024-12-31 C000199 16901 MCGIRR ROAD - 1, SHADY OAKS, WP, 1113 ACSR 2024-01-012024-12-31 C000199 S21-LOSTANT, Distribution, Unattended 2024-12-31 C000199 E71-DORR TWP-1, Distribution, Unattended 2024-12-31 C000199 BES - Residential Space Heating 2024-01-012024-12-31 C000199 1221 DRESDEN - 3, WOLFS, SP, 2156 ACSR 2024-01-012024-12-31 C000199 HEALTH - Analytics DAP HWferc:ElectricUtilityMember 2024-12-31 C000199 17907 DAVIS CREEK - 1, BLOOM, SP, 2156 ACSR 2024-01-012024-12-31 C000199 W349-BENSENVILLE, Distribution, Unattended 2024-01-012024-12-31 C000199 B30-MT MORRIS, Distribution, Unattended 2024-12-31 C000199 AF2-095 Wilmington-Davis Creek561.7 2024-01-012024-12-31 C000199 Chicago North EVCS 2023ferc:ElectricUtilityMember 2024-12-31 C000199 138KV LINES OVERHEAD, , , 2024-01-012024-12-31 C000199 E17-WONDER LAKE, Distribution, Unattended 2024-12-31 C000199 741-PERSHING, Distribution, Unattended 2024-01-012024-12-31 C000199 Insurance Contributions (FICA), Payroll Tax, Fed, 2023 2024-01-012024-12-31 C000199 H28-LYNDON, Distribution, Unattended 2024-01-012024-12-31 C000199 0704 STATE LINE - 1, RIVER E.C., ST, 336.4,477,636,111 2024-01-012024-12-31 C000199 NORTH VO TDC212 NORTHBROOKferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 J76-DUPONT RD, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM J982 Facilities Study921 2024-01-012024-12-31 C000199 Vehicle License-Local, Other License And Fees Tax, IL, 2023 2024-12-31 C000199 20120515-5073, 41044, ER09-1145-000 2024-01-012024-12-31 C000199 450-WASHINGTON ST. JOLIET, Distribution, Unattended 2024-01-012024-12-31 C000199 2024-01-012024-03-31 C000199 465-SOUTH HOLLAND, Distribution, Unattended 2024-12-31 C000199 S12-RANSOM, Distribution, Unattended 2024-01-012024-12-31 C000199 PJM AG1-005 Facilities Study926 2024-01-012024-12-31 C000199 Sawyer TSSferc:LandAndRightsMember 2024-12-31 C000199 Z307-NEWCASTLE, Distribution, Unattended 2024-01-012024-12-31 C000199 Other Debit or Cr. Items (Describe, details in footnote):ferc:ElectricPlantInServiceMemberferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-253 Facilities Study921 2024-01-012024-12-31 C000199 Colette Honorable, Corporate Secretary 2024-01-012024-12-31 C000199 86-DAVIS CREEK-2, Distribution, Unattended 2024-01-012024-12-31 C000199 B51-MARENGO, Distribution, Unattended 2024-12-31 C000199 Human Resources - Indirect, Exelon BSC 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember AF1-048 Belvidere Morengo921 2024-01-012024-12-31 C000199 D114-STICKNEY, Distribution, Unattended 2024-12-31 C000199 I&M Canal Fees to be amortized through June 2033 2024-12-31 C000199 W343-ELMHURST-2, Distribution, Unattended 2024-01-012024-12-31 C000199 J29-GORE ROAD, Distribution, Unattended 2024-12-31 C000199 6721 CONGRESS - 3, ROCKWELL, WP, 1113 ACSR 2024-01-012024-12-31 C000199 165-FORDHAM-2, Distribution, Unattended 2024-12-31 C000199 H14-SANDWICH, Distribution, Unattended 2024-12-31 C000199 487-ARCHER, Distribution, Unattended 2024-01-012024-12-31 C000199 G16-BLUE ISLAND, Distribution, Unattended 2024-12-31 C000199 C78-MORTON GROVE, Distribution, Unattended 2024-12-31 C000199 7611 BLUE ISLAND - 1, WILDWOOD, ST, 900 ACSR 2024-01-012024-12-31 C000199 REACTS1C224303 TDC714-TDC714-4ferc:ElectricUtilityMember 2024-12-31 C000199 16901 TAP, MENDOTA HILLS, SP, 1113 ACSR 2024-01-012024-12-31 C000199 251-ROUND LAKE BEACH, Distribution, Unattended 2024-01-012024-12-31 C000199 513-AURORA-2, Distribution, Unattended 2024-01-012024-12-31 C000199 Electricity Distribution Tax, Other Taxes, IL, 2024 2024-12-31 C000199 C43-EVANSTON, Distribution, Unattended 2024-12-31 C000199 253-SCHAUMBURG, Distribution, Unattended 2024-01-012024-12-31 C000199 127, 3.200% 2024-01-012024-12-31 C000199 G66-OAK LAWN, Distribution, Unattended 2024-12-31 C000199 Distribution Service Costs 2024-12-31 C000199 K40-BOURBONNAIS TWP, Distribution, Unattended 2024-01-012024-12-31 C000199 2019 REACTS TSS945-TSS70 BBFferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 Dynegy Marketing ad Trade, LLC  , OS, 2024-01-012024-12-31 C000199 Compass TUG 138kV L18517ferc:ElectricUtilityMember 2024-12-31 C000199 C87-PARK RIDGE, Distribution, Unattended 2024-01-012024-12-31 C000199 Chicago Use Tax, Sales And Use Tax, IL, 2024 2023-12-31 C000199 AMI Meters 2024-01-012024-12-31 C000199 E70-ARLINGTON HEIGHTS, Distribution, Unattended 2024-01-012024-12-31 C000199 7902 SPAULDING - 1, TOLLWAY, ST, 1113,2156 ACSR 2024-01-012024-12-31 C000199 0703 TAP - 3, RIVER E.C., SP, 477,636, 2024-01-012024-12-31 C000199 505-OAKPARK, Distribution, Unattended 2024-12-31 C000199 W335-WEST CHICAGO-2, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AE2-173: MCLEAN 345 KV921 2024-01-012024-12-31 C000199 AF1-281 Nelson & Lee County408.1 2024-01-012024-12-31 C000199 ferc:OtherUtilityMember Other (Specify) 2024-01-012024-12-31 C000199 ferc:AugustMember 0 2024-01-012024-12-31 C000199 F45-CRETE, Distribution, Unattended 2024-01-012024-12-31 C000199 TSS78 Franklin Park L3705 PST 2024-01-012024-12-31 C000199 J53-BLODGETT RD, Distribution, Unattended 2024-12-31 C000199 Franchise, Franchise Tax, IL, 2024ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 33-HAYFORD, Distribution, Unattended 2024-01-012024-12-31 C000199 Other Projects - 3ferc:ElectricUtilityMember 2024-12-31 C000199 Purchased Receivables Program - Under Recovery 2024-12-31 C000199 85-SKOKIE, Distribution, Unattended 2024-12-31 C000199 Cash Flow Swap Settlement Costs 2024-01-012024-12-31 C000199 Public Utility Fund, Other Taxes, IL, 2024ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 Spare TR 40MVA (2-Wind) Ridgld 2024-01-012024-12-31 C000199 Long-term renewable energy contracts 2024-01-012024-12-31 C000199 1605 WAUKEGAN - 1, HIGHLAND PARK, ST, 1113 ACSR 2024-01-012024-12-31 C000199 B48-RINK, Distribution, Unattended 2024-01-012024-12-31 C000199 J12-BREEN ROAD, Distribution, Unattended 2024-12-31 C000199 15324 TAYLOR, FISK, SP, 2156 ACSR 2024-01-012024-12-31 C000199 0108 LASALLE CO. - 3, SW TIE L-1205, WH, 664.8 ACSS/TW 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-434 Facilities Study921 2024-01-012024-12-31 C000199 0907 JOLIET - 1, WOLFS, ST, 300 CU / 1113 ACW 2024-01-012024-12-31 C000199 Manville-Pontiac 2024-01-012024-12-31 C000199 36-MADISON, Distribution, Unattended 2024-12-31 C000199 D13-FORESTVIEW, Distribution, Unattended 2024-01-012024-12-31 C000199 J15-ELWOOD, Distribution, Unattended 2024-01-012024-12-31 C000199 8604 DAVIS CREEK - 3, BRADLEY, WP, 1113 ACSR 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-128 Crescent Ridge-Cor926 2024-01-012024-12-31 C000199 121, 3.650% 2024-01-012024-12-31 C000199 ferc:ElectricUtilityMember Illinois ITC 2024-12-31 C000199 Gayle Littleton, Corporate Secretary 2024-01-012024-12-31 C000199 0622 BYRON - 2, CHERRY VALLEY, SP, 2156 ACSR 2024-01-012024-12-31 C000199 10721 DIXON - 2, STILLMAN VALLEY, SP, 1113 ACSR, 2-556R 2024-01-012024-12-31 C000199 6605 EAST FRANKFORT - 2, UNIVERSITY PARK, ST, 1113 ACSR 2024-01-012024-12-31 C000199 17713 BURNHAM - 2, WILDWOOD, SP, 1113 ACSR 2024-01-012024-12-31 C000199 W345-ELMHURST-2, Distribution, Unattended 2024-12-31 C000199 1P240004- Replace 69kV bus 2024-01-012024-12-31 C000199 TSS 135 Elmhurst 345kV GISferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 J21-AUX SABLE TWP, Distribution, Unattended 2024-12-31 C000199 11603 GOODINGS GROVE - 3, CRESTWOOD, WP, 1113 ACSR 2024-01-012024-12-31 C000199 PJM AG1-535 Facilities Study408.1 2024-01-012024-12-31 C000199 362439 TSS 300 Keslinger 138kVferc:ElectricUtilityMember 2024-12-31 C000199 0621 BYRON - 2, CHERRY VALLEY, SP, 2156 ACSR 2024-01-012024-12-31 C000199 207-TONNE-1, Distribution, Unattended 2024-12-31 C000199 X315-NEVA #2, Distribution, Unattended 2024-01-012024-12-31 C000199 PJM AG1-535 Facilities Study561.7 2024-01-012024-12-31 C000199 UA HQ Data Center TSS184 2024-01-012024-12-31 C000199 487-ARCHER, Distribution, Unattended 2024-12-31 C000199 0904 JOLIET - 2, DRESDEN, WP, 1113 ACSR 2024-01-012024-12-31 C000199 F73-CHICAGO HEIGHTS, Distribution, Unattended 2024-01-012024-12-31 C000199 11126 ELECTRIC JUNCTION - 1, WAYNE, SP, 2156 ACSR, 2338 ACAR 2024-01-012024-12-31 C000199 1320 CRAWFORD, JEFFERSON, UG, 800 MM2 XLPE 2024-01-012024-12-31 C000199 76-BLUE ISLAND-1, Transmission, Unattended 2024-01-012024-12-31 C000199 PJM AG1-118 Facilities Study926 2024-01-012024-12-31 C000199 16-WAUKEGAN-3, Distribution, Attended 2024-12-31 C000199 E39-ARLINGTON HEIGHTS, Distribution, Unattended 2024-01-012024-12-31 C000199 SPARE TRANSFORMER-5, , 2024-01-012024-12-31 C000199 0708 TAP - 2, HARBOR, SP, 2156 ACSR 2024-01-012024-12-31 C000199 TDC 505 Oak Park Hardeningferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 520 S MAPLEferc:ElectricUtilityMember 2024-12-31 C000199 6P240007 TSS149 12kVferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 17704 BURNHAM - 1, DAVIS CREEK, ST, 2156 ACSR, T2-1113 ACSR, 2338 ACAR 2024-01-012024-12-31 C000199 1227 DRESDEN - 1, MULBERRY, SP, 2156 ACSR, 2-1033.5 ACSS/TW 2024-01-012024-12-31 C000199 C51-DESPLAINES, Distribution, Unattended 2024-12-31 C000199 10804 LOCKPORT - 2, MCCOOK, SP, 2156 ACSR 2024-01-012024-12-31 C000199 AE1-114 PJM Facilities Study921 2024-01-012024-12-31 C000199 L17105 Wood Pole Replacementferc:ElectricUtilityMember 2024-12-31 C000199 821-MARQUETTE PARK, Distribution, Unattended 2024-01-012024-12-31 C000199 12204 TAP, MARENGO, WP, 477, 1113 ACSR, 6 2024-01-012024-12-31 C000199 10322 LISLE - 2, LOMBARD, SP, 2156 ACSR 2024-01-012024-12-31 C000199 General Plant 2024-01-012024-12-31 C000199 572-GILBERTS, Distribution, Unattended 2024-01-012024-12-31 C000199 L19414 Wood Pole Replacementferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 PQ Meters 2024-01-012024-12-31 C000199 D20-MELROSE PARK-2, Distribution, Unattended 2024-01-012024-12-31 C000199 1955 W Hastings - PERMferc:ElectricUtilityMember 2024-12-31 C000199 Insurance recoveries related to third party claims 2024-12-31 C000199 D89-LYONS, Distribution, Unattended 2024-01-012024-12-31 C000199 REACTS1C224303 TDC714-TDC714-2ferc:ElectricUtilityMember 2024-12-31 C000199 213-DEERFIELD, Distribution, Unattended 2024-01-012024-12-31 C000199 NTT Data Center ESSferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 CyrusOne ButterfieldDataCenterferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 ferc:FranchiseTaxMemberferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 141-PLEASANT VALLEY, Transmission, Unattended 2024-01-012024-12-31 C000199 J62-HOMER TWP, Distribution, Unattended 2024-01-012024-12-31 C000199 Legal Department Services, Pepco Holdings LLC 2024-01-012024-12-31 C000199 42-ROUND LAKE-2, Distribution, Unattended 2024-12-31 C000199 D20-MELROSE PARK-1, Distribution, Unattended 2024-01-012024-12-31 C000199 TSS46 Des Plaines TR83 Rplferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 G909-DOLTON-1, Distribution, Unattended 2024-12-31 C000199 D20-MELROSE PARK-1, Distribution, Unattended 2024-12-31 C000199 Communications Services - 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2, WILMINGTON, ST, 1113 ACSR 2024-01-012024-12-31 C000199 F12-SAUK TRAIL, Distribution, Unattended 2024-01-012024-12-31 C000199 70-BRADLEY-1, Distribution, Unattended 2024-01-012024-12-31 C000199 362780: STATE & LAKE/CDOT ZN1ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 ferc:ExciseTaxMemberferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 J21-AUX SABLE TWP, Distribution, Unattended 2024-01-012024-12-31 C000199 10807 LOCKPORT, LOMBARD, SP, T2-1113 ACSR 2024-01-012024-12-31 C000199 B-2, CEA Technologies Inc. Program,588 2024-01-012024-12-31 C000199 1223 DRESDEN - 2, ELECTRIC JUNCTION, ST, 2338 ACAR 2024-01-012024-12-31 C000199 15511 TAP, STERLING, SP, 312.8 AAAC / 1113 2024-01-012024-12-31 C000199 Total, , 2024-01-012024-12-31 C000199 Insurance Contributions (FICA), Payroll Tax, Fed, 2024ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 28201 ZION TDC 282 - 1, IL-WI STATE LINE, ST, 1113 ACSR 2024-01-012024-12-31 C000199 7915 SPAULDING - 1, WAYNE, SP, 1113,2156 ACSR 2024-01-012024-12-31 C000199 G42-WORTH-1, Distribution, Unattended 2024-12-31 C000199 B56-FREEPORT, Distribution, Unattended 2024-01-012024-12-31 C000199 17723 BURNHAM - 1, STATE LINE, SP, 2156 ACSR 2024-01-012024-12-31 C000199 A81-GREAT LAKES, Distribution, Unattended 2024-01-012024-12-31 C000199 A27-WADSWORTH-2, Distribution, Unattended 2024-12-31 C000199 Aligned Data Cented 505 NWferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 TSS101 Itasca 138kV Cap Bank 2024-01-012024-12-31 C000199 X381-CORTLAND, Distribution, Unattended 2024-01-012024-12-31 C000199 0403 QUAD CITIES - 1, CORDOVA, ST, 2-1033.5 ACSS/TW 2024-01-012024-12-31 C000199 131-WEST CHICAGO-2, Distribution, Unattended 2024-01-012024-12-31 C000199 Insurance Contributions (FICA), Payroll Tax, Fed, 2023 2023-12-31 C000199 0704 TAP - 2, TOWER AUTOMOTIVE, WP, 1113 ACSR 2024-01-012024-12-31 C000199 Private LTE Cores & Initia HWferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 2020 REACTS BF-SS851-SS895ferc:ElectricUtilityMember 2024-12-31 C000199 ICC Financing Authority Fees 2023-12-31 C000199 8801 SKOKIE 88 - 2, GOLF MILL, SP, 1113 ACSR 2024-01-012024-12-31 C000199 E21-HARTLAND, Distribution, Unattended 2024-01-012024-12-31 C000199 S37-BRUCE TWP, Distribution, Unattended 2024-01-012024-12-31 C000199 J31-PLAINFIELD, Distribution, Unattended 2024-12-31 C000199 11708 PROSPECT HEIGHTS - 1, APTAKISIC, ST, 1113 ACSR 2024-01-012024-12-31 C000199 C3-HIGHLAND PARK-1, Distribution, Unattended 2024-01-012024-12-31 C000199 GIS Building - TSS51 138kV GIS 2024-01-012024-12-31 C000199 160-ALPINE-1, Distribution, Unattended 2024-01-012024-12-31 C000199 G128-MARKHAM-2, Distribution, Unattended 2024-12-31 C000199 66-EAST FRANKFORT, Transmission, Unattended 2024-12-31 C000199 1206 DRESDEN - 2, CHANNAHON WEST, WP, 1113 ACSR 2024-01-012024-12-31 C000199 225-LANDMEIER, Distribution, Unattended 2024-01-012024-12-31 C000199 9117 CARGO COURT - 1, SHOREWOOD, WH, 1113 AA 2024-01-012024-12-31 C000199 PJM AF2-142 Facilities Study926 2024-01-012024-12-31 C000199 28201 ZION TDC 282 - 2, IL-WI STATE LINE, SP, 1113 ACSR 2024-01-012024-12-31 C000199 PJM AG1-462 Facilities Study921 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM MISO J955 FACILITIES STUDY926 2024-01-012024-12-31 C000199 A87-GRAYS LAKE, Distribution, Unattended 2024-12-31 C000199 J16-EASTERN AVE (JOLIET)-2, Distribution, Unattended 2024-12-31 C000199 ferc:GenerationStudiesMember AF1-280 Nelson Lee County Stud561.7 2024-01-012024-12-31 C000199 Cook County Forest Preserve District License Fees to be amortized through 2027 2024-01-012024-12-31 C000199 W115-GLENWOOD PARK, Distribution, Unattended 2024-12-31 C000199 11701 PROSPECT HTS - 1, DES PLAINES 46, SP, 1113 ACSR 2024-01-012024-12-31 C000199 113, 3.800% 2024-12-31 C000199 12 kV DA IP2 X3980 2024-01-012024-12-31 C000199 Gil Quiniones, President and Chief Executive Officer 2024-01-012024-12-31 C000199 135-ELMHURST-1, Transmission, Unattended 2024-01-012024-12-31 C000199 W236-ROSELLE, Distribution, Unattended 2024-01-012024-12-31 C000199 36-MADISON, Distribution, Unattended 2024-01-012024-12-31 C000199 Long Term Performance Plan - 1ferc:ElectricUtilityMember 2024-12-31 C000199 G125-OAK LAWN, Distribution, Unattended 2024-01-012024-12-31 C000199 1050 W. Van Buren - Permferc:ElectricUtilityMember 2024-12-31 C000199 Apollo Boundary Apps Clferc:ElectricUtilityMember 2024-12-31 C000199 128, 2.200% 2024-12-31 C000199 0627 BYRON - 4, LEE COUNTY E.C., SP, 2156 ACSR 2024-01-012024-12-31 C000199 B27-STILLMAN VALLEY, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:DirectPayrollDistributionMember Stores Expense Undistributed 2024-01-012024-12-31 C000199 Excl HVD,Transf&Meters 2024-01-012024-12-31 C000199 125-NORMANDY, Distribution, Unattended 2024-01-012024-12-31 C000199 Sawyer TSS 2024-01-012024-12-31 C000199 100, 5.875% 2024-01-012024-12-31 C000199 179-BLOOM-1, Transmission, Unattended 2024-01-012024-12-31 C000199 79-SPAULDING-2, Distribution, Unattended 2024-12-31 C000199 11613 GOODINGS GROVE - 2, WILTON CENTER, ST, 2338 ACAR 2024-01-012024-12-31 C000199 A82-ZION, Distribution, Unattended 2024-01-012024-12-31 C000199 Docket No.  23-0773  Rider IMUD 2024-12-31 C000199 H50-EARLVILLE, Distribution, Unattended 2024-12-31 C000199 W384-BUTTERFIELD-2, Distribution, Unattended 2024-12-31 C000199 Docket No.  22-0067  Performance Metrics 2024-12-31 C000199 12-DRESDEN-1, Transmission, Unattended 2024-12-31 C000199 7P230800 - B169 2024-01-012024-12-31 C000199 ATO Monitoring- Chicagoferc:ElectricUtilityMember 2024-12-31 C000199 CloudHQ - E524 & E5220 Feederferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 C33-NILES-1, Distribution, Unattended 2024-12-31 C000199 ferc:GenerationStudiesMember AF1-280 Nelson Lee County Stud926 2024-01-012024-12-31 C000199 454-PLAINFIELD, Distribution, Unattended 2024-01-012024-12-31 C000199 871-56TH STREET, Distribution, Unattended 2024-01-012024-12-31 C000199 C76-LAKE FOREST, Distribution, Unattended 2024-12-31 C000199 18502 TOLLWAY - 2, LIBERTYVILLE, ST, 2156 ACSR 2024-01-012024-12-31 C000199 5104 MCCOOK - 2, BEDFORD PARK, SP, 1113 ACSR, 1033.5 2024-01-012024-12-31 C000199 C66-EVANSTON, Distribution, Unattended 2024-01-012024-12-31 C000199 0703 TAP - 1, LTV STEEL, WP, 477ACSR 2024-01-012024-12-31 C000199 1606 WAUKEGAN - 3, HIGHLAND PARK, SP, 1113,2156 ACSR 2024-01-012024-12-31 C000199 J88-BLUFF ST (JOLIET), Distribution, Unattended 2024-01-012024-12-31 C000199 1221 DRESDEN - 2, WOLFS, ST, 2156 ACSR 2024-01-012024-12-31 C000199 E24-CARY, Distribution, Unattended 2024-12-31 C000199 CSX Midway Airport L5103 Relocferc:ElectricUtilityMember 2024-12-31 C000199 14302 WOLFS - 3, PLANO, SP, 1113,2156 ACSR 2024-01-012024-12-31 C000199 E46-BURTON BRIDGE, Distribution, Unattended 2024-12-31 C000199 513-AURORA-1, Distribution, Unattended 2024-01-012024-12-31 C000199 114, 4.600% 2024-12-31 C000199 19414 SABROOKE - 2, LANCASTER, SP, 1113 ACSR 2024-01-012024-12-31 C000199 J68-COAL CITY, Distribution, Unattended 2024-12-31 C000199 1323 CRAWFORD - 1, CONGRESS, SP, 1113 ACSR 2024-01-012024-12-31 C000199 W12-YORKVILLE, Distribution, Unattended 2024-12-31 C000199 2019 REACTS TDC294-TSS154 BBF 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-253 Facilities Study926 2024-01-012024-12-31 C000199 11-FISK-1, Transmission, Unattended 2024-01-012024-12-31 C000199 126, 4.000% 2024-01-012024-12-31 C000199 1202 DRESDEN - 1, MULBERRY, SP, 2156 ACSR 2024-01-012024-12-31 C000199 12005 LOMBARD, DESPLAINES, ST, 2156 ACSR 2024-01-012024-12-31 C000199 Use Tax, Sales And Use Tax, IL, 2024 2024-12-31 C000199 H70-SUBLETTE, Distribution, Unattended 2024-12-31 C000199 103, 5.900% 2024-12-31 C000199 687-NORWOOD PARK, Distribution, Unattended 2024-12-31 C000199 ITN 362197: Woodstock IL 47ferc:ElectricUtilityMember 2024-12-31 C000199 Information Technology - Indirect, Exelon BSC 2024-01-012024-12-31 C000199 ferc:SalesAndUseTaxMember 2023-12-31 C000199 Franchise, Franchise Tax, IL, 2024 2023-12-31 C000199 409-SOUTH JOLIET, Distribution, Unattended 2024-12-31 C000199 15616 CHERRY VALLEY - 1, SILVER LAKE, ST, 2338 ACAR, 2156 ACSR 2024-01-012024-12-31 C000199 450-WASHINGTON ST. JOLIET, Distribution, Unattended 2024-12-31 C000199 3P230200: Long lead NSCferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 A47-LAKE VILLA, Distribution, Unattended 2024-12-31 C000199 D44-COUNTRYSIDE, Distribution, Unattended 2024-01-012024-12-31 C000199 11613 GOODINGS GROVE - 1, WILTON CENTER, SP, 2156 ACSR, 2338 ACAR 2024-01-012024-12-31 C000199 W336-MILTON TWP, Distribution, Unattended 2024-12-31 C000199 Purchased Electricity - Over Recovery 2024-12-31 C000199 State Income Tax, Income Tax, IL, 2024 2024-12-31 C000199 568-CHURCH ROAD, Distribution, Unattended 2024-12-31 C000199 120-LOMBARD-1, Transmission, Attended 2024-12-31 C000199 E77-CRYSTAL LAKE, Distribution, Unattended 2024-01-012024-12-31 C000199 18702 SCHAUFF ROAD, ROCK FALLS, SP, 2-556.5, 1590ACSR 2024-01-012024-12-31 C000199 J76-DUPONT RD, Distribution, Unattended 2024-12-31 C000199 123-MARENGO, Distribution, Unattended 2024-01-012024-12-31 C000199 H39-MENDOTA, Distribution, Unattended 2024-01-012024-12-31 C000199 14304 WOLFS - 3, PLANO, SP, 1113, 2156 ACSR 2024-01-012024-12-31 C000199 AF2-252 PJM Facilities Study926 2024-01-012024-12-31 C000199 NORTH VO TDC212 NORTHBROOKferc:ElectricUtilityMember 2024-12-31 C000199 See footnote for details 2024-01-012024-12-31 C000199 15624 CHERRY VALLEY - 1, BELVIDERE, ST, 1113 ACSR 2024-01-012024-12-31 C000199 4610 DESPLAINES 46 - 1, GOLF MILL, ST, 1113 ACSR 2024-01-012024-12-31 C000199 D63-SCHILLER PARK, Distribution, Unattended 2024-01-012024-12-31 C000199 13504 ELMHURST - 1, FRANKLIN PARK, ST, 1113 ACSR 2024-01-012024-12-31 C000199 106-MONTGOMERY-1, Distribution, Unattended 2024-01-012024-12-31 C000199 11110 ELECTRIC JUNCTION - 1, WOLFS, ST, 2-556.5,1113 ACSR 2024-01-012024-12-31 C000199 77698:7P230001-TSS113 UPG Distferc:ElectricUtilityMember 2024-12-31 C000199 3P211002-56TH144 12 KV CONVferc:ElectricUtilityMember 2024-12-31 C000199 85-SKOKIE-1, Distribution, Unattended 2024-01-012024-12-31 C000199 J16-EASTERN AVE (JOLIET)-1, Distribution, Unattended 2024-12-31 C000199 Long-Term contracting services 2024-01-012024-12-31 C000199 157-KANKAKEE, Distribution, Unattended 2024-12-31 C000199 PJM AF2-128 Crescent Ridge-Cor408.1 2024-01-012024-12-31 C000199 W26-BIG TIMBER, Distribution, Unattended 2024-01-012024-12-31 C000199 12 kV DA Baseline X1492 2024-01-012024-12-31 C000199 119, 4.350% 2024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-363 Cherry Valley-Glid926 2024-01-012024-12-31 C000199 F122-BLOOM TWP-1, Distribution, Unattended 2024-01-012024-12-31 C000199 Appropriations of retained earnings for future dividend payments 2024-01-012024-12-31 C000199 76-BLUE ISLAND-3, Distribution, Unattended 2024-01-012024-12-31 C000199 674-IRVING PARK, Distribution, Unattended 2024-12-31 C000199 0ferc:UnspecifiedInvestmentsInSubsidiaryCompaniesFourMember 2023-12-31 C000199 ComEd DERMS 2 SWferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 447-SANDRIDGE, Distribution, Unattended 2024-01-012024-12-31 C000199 ComEd FInancing III 2024-01-012024-12-31 C000199 Spare TR 40MVA (2-Wind) Ridgldferc:ElectricUtilityMember 2024-12-31 C000199 127, 3.200% 2024-12-31 C000199 B27-STILLMAN VALLEY, Distribution, Unattended 2024-12-31 C000199 6P240007 TSS149 12kV 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AE2-341 Facility Study561.7 2024-01-012024-12-31 C000199 85-SKOKIE-2, Distribution, Unattended 2024-01-012024-12-31 C000199 1326 CRAWFORD, JEFFERSON, UG, 800 MM2 XLPE 2024-01-012024-12-31 C000199 6721 CONGRESS - 2, ROCKWELL, ST, 1113 ACSR 2024-01-012024-12-31 C000199 128, 2.200% 2024-01-012024-12-31 C000199 123, 3.750% 2024-01-012024-12-31 C000199 X368-SAUGANASH#1, Distribution, Unattended 2024-12-31 C000199 PJM AF2-034 Facilities Study926 2024-01-012024-12-31 C000199 E38-SILVER LAKE, Distribution, Unattended 2024-12-31 C000199 Long-Term Receivable Related to the FERC 494 Refund 2023-12-31 C000199 ferc:GenerationStudiesMember AF2-200 Nelson Elec Junc 345kV921 2024-01-012024-12-31 C000199 570-ELGIN, Distribution, Unattended 2024-01-012024-12-31 C000199 8806 SKOKIE 88 - 2, NORTHBROOK 159, SP, 1113 ACSR 2024-01-012024-12-31 C000199 444-MINOOKA, Distribution, Unattended 2024-01-012024-12-31 C000199 57-FOREST PARK, Distribution, Unattended 2024-12-31 C000199 J49-GOUGAR ROAD, Distribution, Unattended 2024-01-012024-12-31 C000199 Renewable Portfolio Standard Costs - Rider REA 2024-12-31 C000199 4202 SILVER LAKE - 2, SW TIE L-1607, SP, 1113 ACSR 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM J982 Facilities Study926 2024-01-012024-12-31 C000199 SPARE TRANSFORMER-6, , 2024-12-31 C000199 ferc:GenerationStudiesMember AF2-225 McLean 345kV926 2024-01-012024-12-31 C000199 3704Y NATOMA, GALEWOOD, UG, 250 kcmil HPFF 2024-01-012024-12-31 C000199 W51-RANDALL ROAD, Distribution, Unattended 2024-01-012024-12-31 C000199 F75-HOMEWOOD, Distribution, Unattended 2024-12-31 C000199 521-BRISTOL TWP, Distribution, Unattended 2024-01-012024-12-31 C000199 S67-MAZON, Distribution, Unattended 2024-01-012024-12-31 C000199 TC01-PJM Transition Cycle 1408.1 2024-01-012024-12-31 C000199 2003 BRAIDWOOD - 1, E. 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NEETRAC,566 2024-01-012024-12-31 C000199 31-GALEWOOD-2, Distribution, Unattended 2024-12-31 C000199 Tractor Trailers 2024-01-012024-12-31 C000199 RDS - Delivery Service 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-318 Facilities Study561.7 2024-01-012024-12-31 C000199 B17-GENOA-2, Distribution, Unattended 2024-01-012024-12-31 C000199 0902 TAP - 1, DAVIS CREEK, WP, 636 ACSR 2024-01-012024-12-31 C000199 8603 DAVIS CREEK - 1, BRADLEY, ST, 1113 ACSR 2024-01-012024-12-31 C000199 125-NORMANDY, Distribution, Unattended 2024-12-31 C000199 362780: STATE & LAKE/CDOT ZN1 2024-01-012024-12-31 C000199 0ferc:EquityContributionMember 2023-12-31 C000199 240-CARY-2, Distribution, Unattended 2024-12-31 C000199 X310-ALBANY PARK, Distribution, Unattended 2024-01-012024-12-31 C000199 G99-PALOS HEIGHTS, Distribution, Unattended 2024-01-012024-12-31 C000199 7411 KEWANEE , AMEREN KEEMIN, ST, 477 ACSR 2024-01-012024-12-31 C000199 Rochelle Franchise Fees to be amortized through 2070 2024-12-31 C000199 234-LAKEHURST, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-005 Facilities Study921 2024-01-012024-12-31 C000199 Iron Mountain TSS46 DesPlainesferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 12205 BELVIDERE - 2, WOODSTOCK, SP, 2-556.5 ACSR,1113 2024-01-012024-12-31 C000199 ferc:PayrollTaxMemberferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 40-DIVERSEY, Distribution, Unattended 2024-01-012024-12-31 C000199 TSS242 Greenleaf Station Buildferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 Other (provide details in footnote): 2023-01-012023-12-31 C000199 Maywood Outdoor Lab Program 2024-01-012024-12-31 C000199 Wilton Center-Jolietferc:LandAndRightsMember 2024-01-012024-12-31 C000199 H76-SOUTH DIXON, Distribution, Unattended 2024-12-31 C000199 Deferred Income Taxes 2023-12-31 C000199 135-ELMHURST-2, Distribution, Unattended 2024-01-012024-12-31 C000199 REACTS 1C224302 STA13-TSS30-01 2024-01-012024-12-31 C000199 16703 PLANO - 2, ELECTRIC JUNCTION, SP, 2156 ACSR 2024-01-012024-12-31 C000199 558-WESTMONT-2, Distribution, Unattended 2024-12-31 C000199 TSS 146 Sandwich 138kV Stationferc:ElectricUtilityMember 2024-12-31 C000199 1311 CRAWFORD - 2, GOODINGS GROVE, ST, 2156 ACSR 2024-01-012024-12-31 C000199 6606 EAST FRANKFORT - 1, UNIVERSITY PARK, ST, 1113 ACSR 2024-01-012024-12-31 C000199 E10-SOUTH HUNTLEY, Distribution, Unattended 2024-12-31 C000199 380-CHARLES, Distribution, Unattended 2024-01-012024-12-31 C000199 Attachment H-13A of PJM of OATT - Revised, Docket No. ER 19-876-000 2024-01-012024-12-31 C000199 D217-CICERO, Distribution, Unattended 2024-12-31 C000199 A57-BEACH, Distribution, Unattended 2024-01-012024-12-31 C000199 59-CICERO-2, Distribution, Unattended 2024-12-31 C000199 15508 NELSON - 1, DIXON 107, ST, 477,1113 ACSR 2024-01-012024-12-31 C000199 oneMDS Mobile Dispatch - SW 2024-01-012024-12-31 C000199 69-NORTH CHICAGO-1, Distribution, Unattended 2024-01-012024-12-31 C000199 15302 TAYLOR, JEFFERSON, UG, 2000 kcmil HPFF 2024-01-012024-12-31 C000199 Long Term Performance Plan - 6 2024-01-012024-12-31 C000199 EU GIS CORE SWferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 13805 SILVER LAKE - 3, SW TIE L-18513, WP, 1113 ACSR 2024-01-012024-12-31 C000199 Electricity Distribution Tax, Other Taxes, IL, 2024 2024-01-012024-12-31 C000199 2 STEAM PLANT ROAD - 2, TWOMBLY ROAD, SP, 556.5 ACSR 2024-01-012024-12-31 C000199 8801 SKOKIE 88 - 3, GOLF MILL, WP, 1113 ACSR 2024-01-012024-12-31 C000199 Information technology upgrades expenses 2024-01-012024-12-31 C000199 D12-BELLWOOD, Distribution, Unattended 2024-12-31 C000199 1110 FISK, DEKOVEN, UG, 1600 MM2 XLPE 2024-01-012024-12-31 C000199 H18-STERLING, Distribution, Unattended 2024-01-012024-12-31 C000199 Elizabeth Buchanan 2024-01-012024-12-31 C000199 C19-PARK RIDGE-2, Distribution, Unattended 2024-12-31 C000199 362342 : Lisle, Warrenville Rdferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 18618 STEWARD - 2, TWOMBLY ROAD, SP, 556.5 ACSR 2024-01-012024-12-31 C000199 18407 ELK GROVE - 2, TONNE, T, 1113 ACSR 2024-01-012024-12-31 C000199 Transmission Costs - Over Recovery 2023-12-31 C000199 2020 REACTS TDC409-TSS474 BFRferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 Construction, O&M & Admin Fees, ComEd of Indiana 2024-01-012024-12-31 C000199 118-WALLACE, Distribution, Unattended 2024-01-012024-12-31 C000199 15616 CHERRY VALLEY - 2, SILVER LAKE, SP, T2-1113 ACSR 2024-01-012024-12-31 C000199 R21-SUNSET, Distribution, Unattended 2024-12-31 C000199 12 kV DA IP2 X3980ferc:ElectricUtilityMember 2024-12-31 C000199 D40-SUMMIT, Distribution, Unattended 2024-12-31 C000199 Attachment H-13A of PJM of OATT - Revised, Docket No. ER 22-1082-000 2024-01-012024-12-31 C000199 ferc:ElectricUtilityMember 4% 2024-12-31 C000199 111-ELECTRIC JUNCTION-3, Distribution, Unattended 2024-12-31 C000199 X318-MERRIMAC, Distribution, Unattended 2024-01-012024-12-31 C000199 0901 TAP - 4, DAVIS CREEK, ST, 1113 ACSR 2024-01-012024-12-31 C000199 237-BUFFALO GROVE, Distribution, Unattended 2024-12-31 C000199 B-1, EPRI Selected Programs,588 2024-01-012024-12-31 C000199 TSS184 Elk Grove-345kV TR 82 2024-01-012024-12-31 C000199 15310 TAYLOR, GRENSHAW, UG, 1600 MM2 XLPE 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-460 Facilities Study561.7 2024-01-012024-12-31 C000199 6608 EAST FRANKFORT - 1, UNIVERSITY PARK N.  E.C., SP, 2156 ACSR 2024-01-012024-12-31 C000199 5117 MCCOOK - 1, BELLWOOD, SP, 1113 AA / 1113 AC 2024-01-012024-12-31 C000199 834-GRAND CROSSING, Distribution, Unattended 2024-12-31 C000199 Project Barb_PD_7P231400ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-090 Facilities Study921 2024-01-012024-12-31 C000199 S47-SOUTH WILMINGTON, Distribution, Unattended 2024-01-012024-12-31 C000199 D103-RIVERSIDE, Distribution, Unattended 2024-01-012024-12-31 C000199 39-PORTAGE, Distribution, Unattended 2024-01-012024-12-31 C000199 Accumulated under/Over recoveries -local government compliance causes 2024-01-012024-12-31 C000199 2020 REACTS TSS60-TDC461-2 DFRferc:ElectricUtilityMember 2024-12-31 C000199 D16-LAGRANGE HIGHLANDS-1, Distribution, Unattended 2024-12-31 C000199 D292-OAK PARK, Distribution, Unattended 2024-12-31 C000199 AE2-107 Haumesser Rd PJM Study921 2024-01-012024-12-31 C000199 15625 CHERRY VALLEY - 2, WEMPLETOWN, SP, 1113,2-556.5 ASCR 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-034 Facilities Study926 2024-01-012024-12-31 C000199 D46-NORTHLAKE, Distribution, Unattended 2024-12-31 C000199 A56-WAUKEGAN, Distribution, Unattended 2024-01-012024-12-31 C000199 D89-LYONS, Distribution, Unattended 2024-12-31 C000199 501-ELMHURST-2, Distribution, Unattended 2024-12-31 C000199 Sugar Grove TSSferc:LandAndRightsMember 2024-12-31 C000199 Docket No.  24-0304  Annual Formula rate update and revenue reconciliation 2024-12-31 C000199 ferc:ExciseTaxMember 2024-01-012024-12-31 C000199 370-ELEROY, Distribution, Unattended 2024-01-012024-12-31 C000199 F122-BLOOM TWP-1, Distribution, Unattended 2024-12-31 C000199 PJM Interconnection, LLC, OS, 2024-01-012024-12-31 C000199 15912 NORTHBROOK 159 - 2, HIGHLAND PARK, SP, 1113 ACSR,2156 ACSR 2024-01-012024-12-31 C000199 Real Estate Services - Direct, Exelon BSC 2024-01-012024-12-31 C000199 Transmission Costs - Over Recovery 2024-01-012024-12-31 C000199 W38-DOWNERS GROVE TW, Distribution, Unattended 2024-01-012024-12-31 C000199 1324 CRAWFORD - 2, BEDFORD PARK, SP, 2-556.5,1113 ACSR 2024-01-012024-12-31 C000199 PJM AG1-553 Facilities Study926 2024-01-012024-12-31 C000199 13808 SILVER LAKE - 2, CRYSTAL LAKE, WP, 1113 ACSR 2024-01-012024-12-31 C000199 Long Term Performance Plan - 1 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-374 Facilities Study561.7 2024-01-012024-12-31 C000199 132-GARDEN PLAIN-2, Distribution, Unattended 2024-12-31 C000199 L1863/L1864/L1865 Relocationferc:ElectricUtilityMember 2024-12-31 C000199 ferc:GenerationStudiesMember AF2-199 Nelson-Elec Junc 345kV561.7 2024-01-012024-12-31 C000199 ferc:TransmissionStudiesMember PJM AE1-070 Elwood 345 kV Faci921 2024-01-012024-12-31 C000199 129-NILES-1, Distribution, Unattended 2024-12-31 C000199 562-GLENDALE HTS, Distribution, Unattended 2024-12-31 C000199 0ferc:EquityContributionMember 2024-12-31 C000199 30-COLUMBUS PARK-2, Distribution, Unattended 2024-01-012024-12-31 C000199 64-BELLWOOD-2, Distribution, Unattended 2024-01-012024-12-31 C000199 Communications Equipment 2024-01-012024-12-31 C000199 15318 TAYLOR, LASALLE, UG, 2500 kcmil HPFF 2024-01-012024-12-31 C000199 ScheduleElectricPropertyLeasedToOthersAbstract 2024-01-012024-12-31 C000199 16-WAUKEGAN-1, Transmission, Unattended 2024-12-31 C000199 ferc:GenerationStudiesMember AF2-095 Wilmington-Davis Creek408.1 2024-01-012024-12-31 C000199 A41-WAUKEGAN-1, Distribution, Unattended 2024-12-31 C000199 Rebuild 69SK6 2024-01-012024-12-31 C000199 B90-MAPLE PARK, Distribution, Unattended 2024-01-012024-12-31 C000199 Plano-Charter Groveferc:LandAndRightsMember 2024-01-012024-12-31 C000199 250-BARRINGTON HILLS, Distribution, Unattended 2024-01-012024-12-31 C000199 D267-LEYDEN TWP, Distribution, Unattended 2024-01-012024-12-31 C000199 W209-ELGIN, Distribution, Unattended 2024-01-012024-12-31 C000199 B25-MONROE CENTER, Distribution, Unattended 2024-12-31 C000199 PJM AG1-460 Facilities Study921 2024-01-012024-12-31 C000199 Total - 1, , , 2024-01-012024-12-31 C000199 94507 CRETE E.C. - 2, N.I.P.S.CO., SP, 1414 ACSR, 2156 A 2024-01-012024-12-31 C000199 152-BUSSE-1, Distribution, Unattended 2024-12-31 C000199 J15-ELWOOD, Distribution, Unattended 2024-12-31 C000199 7306 CHICAGO HTS. - 2, BLOOM, ST, 1113 ACSR 2024-01-012024-12-31 C000199 PJM AG1-005 Facilities Study561.7 2024-01-012024-12-31 C000199 124, 4.000% 2024-12-31 C000199 PJM AF2-394 Facilities Study561.7 2024-01-012024-12-31 C000199 Other (provide details in footnote): 2024-01-012024-12-31 C000199 840-QUARRY, Distribution, Unattended 2024-12-31 C000199 474-BRIGGS, Distribution, Unattended 2024-12-31 C000199 Coal to Solar 2024-12-31 C000199 ICC Financing Authority Fees 2024-01-012024-12-31 C000199 153-TAYLOR, Transmission, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember AF2-199 Nelson-Elec Junc 345kV926 2024-01-012024-12-31 C000199 PJM AE2-173: MCLEAN 345 KV561.7 2024-01-012024-12-31 C000199 19906 KENSINGTON, CSL BEHRING, SP, 1113 ACSR 2024-01-012024-12-31 C000199 MediterraneanDataCenter-L18402 2024-01-012024-12-31 C000199 E35-HUNTLEY, Distribution, Unattended 2024-12-31 C000199 CyrusOne Wood Dale -ESS 2024-01-012024-12-31 C000199 9806 NEVADA - 1, GOODINGS GROVE, SP, 2-1277 ACAR, 2156 2024-01-012024-12-31 C000199 Miscellaneous Adjustments 2024-01-012024-12-31 C000199 C54-EVANSTON, Distribution, Unattended 2024-01-012024-12-31 C000199 J20-MISSISSIPPI, Distribution, Unattended 2024-01-012024-12-31 C000199 20150415-5322, 42109, ER09-1145-000 2024-01-012024-12-31 C000199 C79-DESPLAINES, Distribution, Unattended 2024-12-31 C000199 Accrued Vacation Pay 2024-01-012024-12-31 C000199 521-BRISTOL TWP, Distribution, Unattended 2024-12-31 C000199 EU GIS DQ SWferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 11708 PROSPECT HEIGHTS - 2, APTAKISIC, SP, 266.8, 636, 1113A 2024-01-012024-12-31 C000199 A41-WAUKEGAN-1, Distribution, Unattended 2024-01-012024-12-31 C000199 A92-WARREN, Distribution, Unattended 2024-12-31 C000199 Financial Services - Direct, Exelon BSC 2024-01-012024-12-31 C000199 11124 ELECTRIC JUNCTION - 1, LOMBARD, ST, 2335 ACAR 2024-01-012024-12-31 C000199 PJM AF2-392 Facilities Study926 2024-01-012024-12-31 C000199 390-SOUTH PECATONICA, Distribution, Unattended 2024-12-31 C000199 B36-POLO, Distribution, Unattended 2024-01-012024-12-31 C000199 PJM AF1-296 Facilities Study921 2024-01-012024-12-31 C000199 Pine TUG 138kV L10109-Tferc:ElectricUtilityMember 2024-12-31 C000199 Retire 4kV Fdrs W405 W406 W438ferc:ElectricUtilityMember 2024-12-31 C000199 220-SOUTH SCHAUMBURG, Distribution, Unattended 2024-01-012024-12-31 C000199 6102 TAP, MARSEILLES S.S., WP, 477 ACSR 2024-01-012024-12-31 C000199 Attachment H-13A of PJM of OATT - Revised, Docket No. ER10-1247-000 2024-01-012024-12-31 C000199 38-HUMBOLDT PARK-1, Distribution, Unattended 2024-12-31 C000199 11102 ELECTRIC JUNCTION - 2, WOLFS, SP, 1113 ACSR 2024-01-012024-12-31 C000199 MISO J1377 - PJM Facilities921 2024-01-012024-12-31 C000199 1P250001-New Rockwell TDCferc:ElectricUtilityMember 2024-12-31 C000199 D17-WINSTON PARK, Distribution, Unattended 2024-12-31 C000199 X304-CHASE, Distribution, Unattended 2024-12-31 C000199 Long Term receivable from Constellation Energy Generation, LLC (formerly Exelon Generation Company, LLC) (SFAS 143, Regulatory Liability offset) 2024-12-31 C000199 PJM AF1-030 Facility Study408.1 2024-01-012024-12-31 C000199 2020 REACTS DF-TSS60-TSS115-01 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AE2-173: MCLEAN 345 KV926 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-183- Nelson Lee County561.7 2024-01-012024-12-31 C000199 K23-KANKAKEE, Distribution, Unattended 2024-12-31 C000199 679-BESLEY COURT, Distribution, Unattended 2024-12-31 C000199 Z312-EXCHANGE, Distribution, Unattended 2024-12-31 C000199 Long Term Performance Plan - 11ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 1P240004- Replace 69kV busferc:ElectricUtilityMember 2024-12-31 C000199 184-ELK GROVE, Distribution, Unattended 2024-12-31 C000199 C34-BRAESIDE, Distribution, Unattended 2024-12-31 C000199 ferc:FranchiseTaxMember 2023-12-31 C000199 102-PALATINE-2, Distribution, Unattended 2024-12-31 C000199 38-HUMBOLDT PARK-2, Distribution, Unattended 2024-01-012024-12-31 C000199 J12-BREEN ROAD, Distribution, Unattended 2024-01-012024-12-31 C000199 76-BLUE ISLAND-3, Distribution, Unattended 2024-12-31 C000199 C25-GLENVIEW, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember AF1-280 Nelson Lee County Stud408.1 2024-01-012024-12-31 C000199 121, 3.650% 2024-12-31 C000199 Auto Transformers at TSS192ferc:ElectricUtilityMember 2024-12-31 C000199 ferc:GenerationStudiesMember AF-2041 Nelson-Elec Junc 345kV926 2024-01-012024-12-31 C000199 0708 STATE LINE - 1, CALUMET, ST, 750 CU / 1113,215 2024-01-012024-12-31 C000199 111-ELECTRIC JUNCTION-3, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-553 Facilities Study926 2024-01-012024-12-31 C000199 D241-RIVERSIDE, Distribution, Unattended 2024-01-012024-12-31 C000199 28 E Garfield-Washington Park 2024-01-012024-12-31 C000199 3707 NATOMA, NORRIDGE, UG, 2000 kcmil HPFF 2024-01-012024-12-31 C000199 A27-WADSWORTH-1, Distribution, Unattended 2024-01-012024-12-31 C000199 553-HINSDALE, Distribution, Unattended 2024-01-012024-12-31 C000199 BES H - 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4, SW TIE L-1205, ST, 300CU,477ACS 2024-01-012024-12-31 C000199 422-MORRIS, Distribution, Unattended 2024-01-012024-12-31 C000199 B95-SOUTH DEKALB, Distribution, Unattended 2024-01-012024-12-31 C000199 553-HINSDALE, Distribution, Unattended 2024-12-31 C000199 ferc:GenerationStudiesMember AF2-225 McLean 345kV561.7 2024-01-012024-12-31 C000199 11602 GOODINGS GROVE - 2, EAST FRANKFORT, SP, 2-1033.5ACSS/TW 2024-01-012024-12-31 C000199 193-MCHENRY-2, Distribution, Unattended 2024-12-31 C000199 D16-LAGRANGE HIGHLANDS-2, Distribution, Unattended 2024-12-31 C000199 ferc:UnemploymentTaxMember 2024-01-012024-12-31 C000199 1680 E TOUHYferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-435 Facilities Study561.7 2024-01-012024-12-31 C000199 PJM AE2-173: MCLEAN 345 KV408.1 2024-01-012024-12-31 C000199 8823 SKOKIE 88 - 2, GOLF MILL, ST, 2156 ACSR 2024-01-012024-12-31 C000199 TSS192 Ridgeland TR71 Replcmnt 2024-01-012024-12-31 C000199 S36-VERONA, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-070 Facilities Study561.7 2024-01-012024-12-31 C000199 577-SOUTH ELGIN-2, Distribution, Unattended 2024-01-012024-12-31 C000199 37-NATOMA, Distribution, Unattended 2024-12-31 C000199 L13349- River Crossing INS CBLferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 Unemployment Insurance (SUTA), Unemployment Tax, IL, 2024 2024-12-31 C000199 D103-RIVERSIDE, Distribution, Unattended 2024-12-31 C000199 149-WILMINGTON, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-031 Facility Study561.7 2024-01-012024-12-31 C000199 A64-LIBERTYVILLE, Distribution, Unattended 2024-12-31 C000199 ferc:GenerationStudiesMember PJM AE2-341 Facility Study926 2024-01-012024-12-31 C000199 101-ITASCA-2, Distribution, Unattended 2024-12-31 C000199 8302 GLIDDEN, CREGO ROAD, SP, 2-556.5 ACSR, 2156 ACSR 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-005 Facilities Study408.1 2024-01-012024-12-31 C000199 6604 EAST FRANKFORT - 1, MATTESON, ST, 477, 664.8 ACSS/T 2024-01-012024-12-31 C000199 10111 ITASCA, DESPLAINES 46, ST, 2156 ACSR 2024-01-012024-12-31 C000199 H27-GALT, Distribution, Unattended 2024-01-012024-12-31 C000199 11413 NORTHWEST, CLYBOURN-CROSBY, SP, 1113 ACSR 2024-01-012024-12-31 C000199 R35-FOURTEENTH ST., Distribution, Unattended 2024-01-012024-12-31 C000199 K45-ST.ANNE, Distribution, Unattended 2024-01-012024-12-31 C000199 135-ELMHURST-2, Distribution, Unattended 2024-12-31 C000199 120, 2.550% 2024-12-31 C000199 ferc:GenerationStudiesMember AF2-349 Garden Prairie 345 kV408.1 2024-01-012024-12-31 C000199 2020 REACTS STA18-TSS60 DFRferc:ElectricUtilityMember 2024-12-31 C000199 2107 MT. PULASKI - 2, LANESVILLE (AMEREN), ST, 2-1277 ACAR 2024-01-012024-12-31 C000199 116, 4.700% 2024-12-31 C000199 J87-LEMONT, Distribution, Unattended 2024-01-012024-12-31 C000199 REACTS 1C224302 TSS30-TSS30-1ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 4202 SILVER LAKE - 1, SW TIE L-1607, ST, 300 CU / 477,1113 2024-01-012024-12-31 C000199 56-NORTH AURORA-2, Distribution, Unattended 2024-01-012024-12-31 C000199 Overhead Line Expenses, , , 2024-01-012024-12-31 C000199 3% 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember 2024-01-012024-12-31 C000199 E82-RICHMOND, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM J982 Facilities Study561.7 2024-01-012024-12-31 C000199 D351-HODGINS, Distribution, Unattended 2024-01-012024-12-31 C000199 5P2302: new feeder D3429ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 B45-LENA, Distribution, Unattended 2024-01-012024-12-31 C000199 S21-LOSTANT, Distribution, Unattended 2024-01-012024-12-31 C000199 174-UNIVERSITY, Distribution, Unattended 2024-12-31 C000199 Increases (Decreases) from Sales of Donations Received from Stockholders 2024-01-012024-12-31 C000199 F115-THORNTON, Distribution, Unattended 2024-01-012024-12-31 C000199 15913 NORTHBROOK 159 - 1, HIGHLAND PARK, ST, 1113 ACSR 2024-01-012024-12-31 C000199 W44-LISLE, Distribution, Unattended 2024-01-012024-12-31 C000199 47-EVANSTON-1, Distribution, Unattended 2024-01-012024-12-31 C000199 20200515-5181, 43966, ER09-1145-000 2024-01-012024-12-31 C000199 Real Estate, Property Tax, IL, 2023ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 B-2, Georgia Tech Research Corp. - NEETRAC,588 2024-01-012024-12-31 C000199 1206 TAP, EQUISTAR, SP, 2024-01-012024-12-31 C000199 17113 SABROOKE - 4, WEMPLETOWN, WH, 1113 ACSR 2024-01-012024-12-31 C000199 80-PONTIAC MIDPOINT-1, Transmission, Unattended 2024-01-012024-12-31 C000199 PJM AF1-090 Facilities Study921 2024-01-012024-12-31 C000199 X318-MERRIMAC, Distribution, Unattended 2024-12-31 C000199 Dividends declared 2024-12-31 C000199 RT 53 & RT 56 DUPAGE COUNTY 2024-01-012024-12-31 C000199 1324 CRAWFORD, HAYFORD, UG, 1600 MM2 XLPE 2024-01-012024-12-31 C000199 GDVA Implementation SWferc:ElectricUtilityMember 2024-12-31 C000199 43-WILDWOOD-1, Distribution, Unattended 2024-01-012024-12-31 C000199 23-0610, 23-0622, 23-0675, 23-0710, 23-0722, 23-0731, 2024-01-012024-12-31 C000199 558-WESTMONT-1, Distribution, Unattended 2024-01-012024-12-31 C000199 15410 LIBERTYVILLE - 2, APTAKISIC, SP, 1113 ACSR 2024-01-012024-12-31 C000199 PJM Facilities Studies561.7 2024-01-012024-12-31 C000199 0ferc:CaptialStockMember 2024-12-31 C000199 ferc:AllocationOfPayrollChargedForClearingAccountsMember Clearing Accounts 2024-01-012024-12-31 C000199 C32-SKOKIE, Distribution, Unattended 2024-12-31 C000199 PJM AF2-226 Facilities Study926 2024-01-012024-12-31 C000199 Northpoint Elwood Phase 2ferc:ElectricUtilityMember 2024-12-31 C000199 644 Madison, Oak Park - Perm 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember AF2-252 PJM Facilities Study926 2024-01-012024-12-31 C000199 Other Debit or Cr. Items (Describe, details in footnote): 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-030 Facility Study926 2024-01-012024-12-31 C000199 133, 3.850% 2024-01-012024-12-31 C000199 A87-GRAYS LAKE, Distribution, Unattended 2024-01-012024-12-31 C000199 88-SKOKIE-2, Distribution, Unattended 2024-12-31 C000199 0622 BYRON - 1, CHERRY VALLEY, ST, 2156 ACSR, 2338 A 2024-01-012024-12-31 C000199 648-NORRIDGE, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-096 Facilities Study926 2024-01-012024-12-31 C000199 B19-BELVIDERE-1, Distribution, Unattended 2024-01-012024-12-31 C000199 S41-EPPARDS POINT, Distribution, Unattended 2024-01-012024-12-31 C000199 D67-LEYDEN TWP, Distribution, Unattended 2024-01-012024-12-31 C000199 11620 GOODINGS GROVE - 2, ELWOOD, SP, 2156/T2-1113 ACSR 2024-01-012024-12-31 C000199 DRW Energy Trading LLC, OS, 2024-01-012024-12-31 C000199 ComED VO Refresh SWferc:ElectricUtilityMember 2024-12-31 C000199 Mercuria Energy America, LLC, OS, 2024-01-012024-12-31 C000199 K34-LEHIGH, Distribution, Unattended 2024-01-012024-12-31 C000199 17008 HARBOR, UNIVERSITY, SP, 1113,2156 ACSR 2024-01-012024-12-31 C000199 133-ROCK FALLS-1, Distribution, Unattended 2024-12-31 C000199 14405 WAYNE - 2, AURORA E.C., SP, 1113 ACSR 2024-01-012024-12-31 C000199 15622 CHERRY VALLEY - 1, SABROOKE, ST, 1113 ACSR 2024-01-012024-12-31 C000199 851-WASHTENAW, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:SalesAndUseTaxMemberferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 E18-HONEY LAKE, Distribution, Unattended 2024-12-31 C000199 109-APTAKISIC, Distribution, Unattended 2024-12-31 C000199 45-JEFFERSON-2, Distribution, Unattended 2024-01-012024-12-31 C000199 W148-AURORA TWP-1, Distribution, Unattended 2024-01-012024-12-31 C000199 D111-ELMWOOD PARK, Distribution, Unattended 2024-12-31 C000199 176-STILLMAN VALLEY, Distribution, Unattended 2024-01-012024-12-31 C000199 77698:7P230001-TSS113 UPG Dist 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-236 Facilities Study926 2024-01-012024-12-31 C000199 127-MATTESON-2, Distribution, Unattended 2024-01-012024-12-31 C000199 59306 WILLOW SPRINGS - 1, BURR RIDGE, ST, 1113 ACSR 2024-01-012024-12-31 C000199 4622 DESPLAINES - 1, GOLF MILL, ST, 2156 ACSR 2024-01-012024-12-31 C000199 4620 DESPLAINES 46, PROSPECT HTS, 117, ST, 2156 ACSR 2024-01-012024-12-31 C000199 C6-MORTON GROVE, Distribution, Unattended 2024-01-012024-12-31 C000199 2310 COLLINS - 1, KENDALL CO., SP, 2156 ACSR 2024-01-012024-12-31 C000199 PJM AF2-031 Facility Study921 2024-01-012024-12-31 C000199 ferc:UnemploymentTaxMember 2024-12-31 C000199 REACTS1C224303 TDC714-TDC714-4ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-296 Facilities Study926 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember MISO J1377 - PJM Facilities561.7 2024-01-012024-12-31 C000199 458-GREEN LAKE, Distribution, Unattended 2024-01-012024-12-31 C000199 L17401 Leak Repairferc:ElectricUtilityMember 2024-12-31 C000199 D99-FRANKLIN PARK-1, Distribution, Unattended 2024-01-012024-12-31 C000199 83-GLIDDEN-2, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:ElectricUtilityMember 10% 2023-12-31 C000199 17101 WEMPLETOWN - 1, ATC INTERCONNECTION, ST, 2156 ACSR 2024-01-012024-12-31 C000199 154-LIBERTYVILLE-1, Transmission, Unattended 2024-01-012024-12-31 C000199 31 items less than $250,000 2024-01-012024-12-31 C000199 135-ELMHURST-1, Transmission, Unattended 2024-12-31 C000199 G30-CALUMET CITY, Distribution, Unattended 2024-12-31 C000199 B32-GARDEN PRAIRIE, Distribution, Unattended 2024-01-012024-12-31 C000199 oneMDS Mobile Dispatch - SWferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 Upgrade 345kV L97008 2024-01-012024-12-31 C000199 C32-SKOKIE, Distribution, Unattended 2024-01-012024-12-31 C000199 Deferred Income Taxes 2023-12-31 C000199 559-WOODRIDGE, Distribution, Unattended 2024-12-31 C000199 D244-STICKNEY TWP, Distribution, Unattended 2024-01-012024-12-31 C000199 E8-NERGE, Distribution, Unattended 2024-12-31 C000199 ADMS - Cap Software #2 SWferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember AF2-200 Nelson Elec Junc 345kV561.7 2024-01-012024-12-31 C000199 D15-CICERO, Distribution, Unattended 2024-12-31 C000199 Capitalized Employee Incentive Payments 2024-01-012024-12-31 C000199 ferc:TransmissionStudiesMember PJM AE1-070 Elwood 345 kV Faci561.6 2024-01-012024-12-31 C000199 Z305-KEATING, Distribution, Unattended 2024-12-31 C000199 Parallel Operation of Retail Customer Generating Facilities Community Supply 2024-01-012024-12-31 C000199 88-SKOKIE-1, Transmission, Unattended 2024-01-012024-12-31 C000199 Real Estate Services - Indirect, Exelon BSC 2024-01-012024-12-31 C000199 179-BLOOM-2, Distribution, Unattended 2024-01-012024-12-31 C000199 54-CLYBOURN, Distribution, Unattended 2024-01-012024-12-31 C000199 18408 ELK GROVE - 2, TONNE, T, 1113 ACSR 2024-01-012024-12-31 C000199 W334-VILLA PARK-2, Distribution, Unattended 2024-01-012024-12-31 C000199 0ferc:OtherInvestmentsInSubsidiaryCompaniesMember 2024-01-012024-12-31 C000199 Laboratory Equipment 2024-01-012024-12-31 C000199 143-WOLFS CROSSING, Transmission, Unattended 2024-01-012024-12-31 C000199 INSTALL 3RD TR (40MVA) AT TDC2 2024-01-012024-12-31 C000199 Rebuild L15518-TSS132 & TSS133ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 126-STATE, Distribution, Unattended 2024-12-31 C000199 Capital Lease Excess Depreciation 2023-12-31 C000199 0ferc:UnspecifiedInvestmentsInSubsidiaryCompaniesThreeMember 2023-12-31 C000199 C95-GLENVIEW, Distribution, Unattended 2024-12-31 C000199 Balance - Beginning of Year (Debit or Credit) 2024-01-012024-12-31 C000199 F149-LYNWOOD, Distribution, Unattended 2024-12-31 C000199 TSS242 Greenleaf Station Build 2024-01-012024-12-31 C000199 674-IRVING PARK, Distribution, Unattended 2024-01-012024-12-31 C000199 1202 DRESDEN - 2, MULBERRY, ST, 2338 ACAR 2024-01-012024-12-31 C000199 34-KINGSBURY, Distribution, Unattended 2024-12-31 C000199 A47-LAKE VILLA, Distribution, Unattended 2024-01-012024-12-31 C000199 B42-PEARL CITY, Distribution, Unattended 2024-12-31 C000199 14405 WAYNE - 1, AURORA E.C., ST, 1113 ACSR 2024-01-012024-12-31 C000199 PJM AG1-460 Facilities Study408.1 2024-01-012024-12-31 C000199 14302 WOLFS - 1, PLANO, SP, 1113 ACSR 2024-01-012024-12-31 C000199 118-WALLACE, Distribution, Unattended 2024-12-31 C000199 Sales Tax, Sales And Use Tax, IL, 2024 2023-12-31 C000199 H76-SOUTH DIXON, Distribution, Unattended 2024-01-012024-12-31 C000199 STA11 Fisk Cap Bank 2024-01-012024-12-31 C000199 S43-ODELL, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember AF1-281 Nelson & Lee County926 2024-01-012024-12-31 C000199 ferc:OperatingUtilityMember 2024-12-31 C000199 416-BELL ROAD, Distribution, Unattended 2024-12-31 C000199 C90-SKOKIE, Distribution, Unattended 2024-01-012024-12-31 C000199 PJM Facilities Studies921 2024-01-012024-12-31 C000199 0ferc:OtherInvestmentsInSubsidiaryCompaniesMember 2023-12-31 C000199 ferc:OtherLicenseAndFeesTaxMember 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember AE1-114 PJM Facilities Study921 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-535 Facilities Study926 2024-01-012024-12-31 C000199 S36-VERONA, Distribution, Unattended 2024-12-31 C000199 SS674 12kV Relay Upgd SCADAferc:ElectricUtilityMember 2024-12-31 C000199 16914 TAP - 2, RITCHIE ROAD, SP, 556.5, 1113 ACSR, T2-556.5 ACSR 2024-01-012024-12-31 C000199 111-ELECTRIC JUNCTION-1, Transmission, Unattended 2024-01-012024-12-31 C000199 12kV DA Program - Z17450 2024-01-012024-12-31 C000199 1321 CRAWFORD - 2, CONGRESS, ST, 1113 ACSR 2024-01-012024-12-31 C000199 17712 BURNHAM - 1, CHICAGO HTS, SP, 1113 ACSR 2024-01-012024-12-31 C000199 17723 STATE LINE - 1, TAYLOR, SP, 2156 ACSR, 2-1277 ACAR 2024-01-012024-12-31 C000199 Apollo Boundary Apps SWferc:ElectricUtilityMember 2024-12-31 C000199 SPARE TRANSFORMER-11, , 2024-12-31 C000199 Long Term Performance Plan - 9 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-069 Facilities Study926 2024-01-012024-12-31 C000199 H91-PROPHETSTOWN, Distribution, Unattended 2024-01-012024-12-31 C000199 Other: Contributions from Parent 2024-01-012024-12-31 C000199 89-BEVERLY, Distribution, Unattended 2024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-350926 2024-01-012024-12-31 C000199 160-ALPINE-2, Distribution, Unattended 2024-01-012024-12-31 C000199 7307 CHICAGO HTS. - 3, BURNHAM, WP, 1113 ACSR 2024-01-012024-12-31 C000199 0101 LASALLE - 2, PLANO, SP, 2-1277 ACAR 2024-01-012024-12-31 C000199 E28-ALGONQUIN, Distribution, Unattended 2024-12-31 C000199 G31-RIVERDALE, Distribution, Unattended 2024-01-012024-12-31 C000199 160-ALPINE-2, Distribution, Unattended 2024-12-31 C000199 Low Income Tax, Other Taxes, IL, 2024 2023-12-31 C000199 MISO J1377 - PJM Facilities408.1 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-314 Facilities Study921 2024-01-012024-12-31 C000199 EUN Refresh 2023 HWferc:ElectricUtilityMember 2024-12-31 C000199 15410 LIBERTYVILLE - 1, APTAKISIC, ST, 1113 ACSR 2024-01-012024-12-31 C000199 345KV LINES, , , 2024-01-012024-12-31 C000199 Cloud HQ Data Center-ESSE410 2024-01-012024-12-31 C000199 X313-MONTROSE, Distribution, Unattended 2024-01-012024-12-31 C000199 113-WATERMAN, Distribution, Unattended 2024-12-31 C000199 REACTS 1C224302 STA13-TSS30-01ferc:ElectricUtilityMember 2024-12-31 C000199 Waukegan Station 354kv Switchyard 2024-01-012024-12-31 C000199 135, 5.300% 2024-01-012024-12-31 C000199 Microgrid Prepayment 2023-12-31 C000199 Other 2024-12-31 C000199 C77-SKOKIE, Distribution, Unattended 2024-01-012024-12-31 C000199 0102 LASALLE - 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Van Buren - Permferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 W50-DEERPATH, Distribution, Unattended 2024-01-012024-12-31 C000199 Long-term contracting services 2023-12-31 C000199 ScheduleNuclearFuelMaterialsAbstract 2024-01-012024-12-31 C000199 470-ORLAND, Distribution, Unattended 2024-01-012024-12-31 C000199 W384-BUTTERFIELD-1, Distribution, Unattended 2024-01-012024-12-31 C000199 AF2-143 Powerton- Nevada 345kV921 2024-01-012024-12-31 C000199 124-MARYLAND, Distribution, Unattended 2024-12-31 C000199 PJM AG1-434 Facilities Study561.7 2024-01-012024-12-31 C000199 ferc:SulfurDioxideMember Allowances Used 2024-01-012024-12-31 C000199 5810 MADISON, GRAND, UG, 1600 MM2 XLPE 2024-01-012024-12-31 C000199 443-HARVEY, Distribution, Unattended 2024-01-012024-12-31 C000199 C55-PARK RIDGE, Distribution, Unattended 2024-12-31 C000199 11120 ELECTRIC JUNCTION - 2, LOMBARD, ST, 2338 ACAR 2024-01-012024-12-31 C000199 PJM AG1-462 Facilities Study408.1 2024-01-012024-12-31 C000199 126, 4.000% 2024-12-31 C000199 ferc:ElectricUtilityMember Illinois ITC 2024-01-012024-12-31 C000199 W346-ADDISON TWP, Distribution, Unattended 2024-01-012024-12-31 C000199 0907 JOLIET - 2, WOLFS, SP, 1113 ACSR 2024-01-012024-12-31 C000199 PD# 3P233700 IP2 4/12kV THRP42 2024-01-012024-12-31 C000199 Attachment H-13A of PJM of OATT - Revised, Docket No. ER13-1391-000 2024-01-012024-12-31 C000199 J55-BROADWAY ST, Distribution, Unattended 2024-12-31 C000199 B20-BELVIDERE, Distribution, Unattended 2024-01-012024-12-31 C000199 Stream Data Center 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember MISO J1377 - PJM Facilities926 2024-01-012024-12-31 C000199 R24-FOURTH AVE., Distribution, Unattended 2024-01-012024-12-31 C000199 2020 REACTS BF-TSS63-SS851 2024-01-012024-12-31 C000199 13806 SILVER LAKE - 1, SW TIE L-18512, ST, 1277.2 ACAR, 477, 2024-01-012024-12-31 C000199 A94-DRUCE LAKE, Distribution, Unattended 2024-12-31 C000199 121-FREEPORT, Distribution, Unattended 2024-01-012024-12-31 C000199 78-FRANKLIN PARK-2, Distribution, Unattended 2024-01-012024-12-31 C000199 Docket No. 24-0163 Low Income Rate Study 2024-12-31 C000199 C92-GLENCOE, Distribution, Unattended 2024-12-31 C000199 Project Post - 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1, NAPERVILLE, SP, 1113 ACSR 2024-01-012024-12-31 C000199 875-THROOP, Distribution, Unattended 2024-12-31 C000199 480-VETERANS, Distribution, Unattended 2024-01-012024-12-31 C000199 C62-GLENCOE-1, Distribution, Unattended 2024-12-31 C000199 W33-WAYNE, Distribution, Unattended 2024-12-31 C000199 Attachment H-13A of PJM of OATT - Revised, Docket No. ER15-959-000 2024-01-012024-12-31 C000199 Initial payments - contracts 2023-12-31 C000199 I&M Canal Fees to be amortized through June 2033 2024-01-012024-12-31 C000199 Sales Tax, Sales And Use Tax, IL, 2024 2024-12-31 C000199 11413 NORTHWEST, DIVERSEY, UG, 2000 kcmil HPFF,2 2024-01-012024-12-31 C000199 PJM AF2-142 Facilities Study561.7 2024-01-012024-12-31 C000199 C81-LINCOLNWOOD, Distribution, Unattended 2024-12-31 C000199 C25-GLENVIEW, Distribution, Unattended 2024-12-31 C000199 17102 WEMPLETOWN - 1, ATC INTERCONNECTION, ST, 2156 ACSR 2024-01-012024-12-31 C000199 PJM AF2-069 Facilities Study921 2024-01-012024-12-31 C000199 J32-KAHLER RD, Distribution, Unattended 2024-12-31 C000199 Transfer to appropriated retained earnings for payment of future dividends 2023-01-012023-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-296 Facilities Study921 2024-01-012024-12-31 C000199 156-CHERRY VALLEY, Transmission, Unattended 2024-01-012024-12-31 C000199 7P240001-TDC375 new transferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 Smita Shah 2024-01-012024-12-31 C000199 1802 WILL COUNTY - 1, ARGONNE, ST, 1113 ACSR 2024-01-012024-12-31 C000199 435-COUNTRY CLUB HILLS, Distribution, Unattended 2024-12-31 C000199 Legal Governance - Direct, Exelon BSC 2024-01-012024-12-31 C000199 11103 ELECTRIC JUNCTION - 2, AURORA E.C., ST, 1113 ACSR 2024-01-012024-12-31 C000199 19414 SABROOKE - 3, LANCASTER, WP, 1113 ACSR 2024-01-012024-12-31 C000199 PJM Interconnection L.L.C.  OS 2024-01-012024-12-31 C000199 1310 CRAWFORD, FISK, SP, T2-1113 ACSR 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember AF-2041 Nelson-Elec Junc 345kV408.1 2024-01-012024-12-31 C000199 AF2-352 PJM Facilities Study408.1 2024-01-012024-12-31 C000199 0716 ILL-IND STATE LINE - 1, CALUMET, WP, 1113 ACSR 2024-01-012024-12-31 C000199 B15-KINGSTON, Distribution, Unattended 2024-12-31 C000199 11124 ELECTRIC JUNCTION - 3, LOMBARD, ST, 2338 ACAR 2024-01-012024-12-31 C000199 S29-GRAND RIDGE, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:NitrogenOxideMember Allowances Used 2024-01-012024-12-31 C000199 Transmission Services, Baltimore Gas & Electric 2024-01-012024-12-31 C000199 Long-term contracting services 2024-12-31 C000199 Cloud HQ Data Center-ESSE410ferc:ElectricUtilityMember 2024-12-31 C000199 C96-TECHNY SOUTH, Distribution, Unattended 2024-12-31 C000199 REACTS Fiber Program 2023-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-096 Facilities Study921 2024-01-012024-12-31 C000199 11606 GOODINGS GROVE, BEDFORD PARK, ST, 900 ACSR 2024-01-012024-12-31 C000199 Balance - 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1, GOLF MILL, SP, 2156 ACSR 2024-01-012024-12-31 C000199 TSS192 Ridgeland - TR71 Matrlferc:ElectricUtilityMember 2024-12-31 C000199 B49-KENT, Distribution, Unattended 2024-12-31 C000199 B19-BELVIDERE-2, Distribution, Unattended 2024-12-31 C000199 Other, Baltimore Gas & Electric 2024-01-012024-12-31 C000199 1P190001-Install 5th TRferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 TSS184 Third TRferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 F91-CHICAGO HEIGHTS, Distribution, Unattended 2024-01-012024-12-31 C000199 Chicago Use Tax, Sales And Use Tax, IL, 2024 2024-12-31 C000199 15315 LASALLE, STATE, UG, 1200 MM2 XPLE 2024-01-012024-12-31 C000199 AF-2041 Nelson-Elec Junc 345kV561.7 2024-01-012024-12-31 C000199 60-ALSIP-1, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-374 Facilities Study926 2024-01-012024-12-31 C000199 D204-OAK PARK, Distribution, Unattended 2024-01-012024-12-31 C000199 14304 WOLFS - 2, PLANO, WP, 477,1113 2024-01-012024-12-31 C000199 Stores Expense Undistributed 2024-01-012024-12-31 C000199 11617 GOODINGS GROVE - 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Phase 2 & 3ferc:ElectricUtilityMember 2024-12-31 C000199 PJM AG1-118 Facilities Study408.1 2024-01-012024-12-31 C000199 4522 FISK, JEFFERSON, UG, 2500 kcmil HPFF 2024-01-012024-12-31 C000199 17714 BURNHAM - 1, WILDWOOD, ST, 900,1113 ACSR 2024-01-012024-12-31 C000199 48-HIGHLAND PARK-2, Distribution, Unattended 2024-01-012024-12-31 C000199 Zero Emissions Program 2023-12-31 C000199 Renewable Portfolio Standard Costs - ACP Funds 2024-01-012024-12-31 C000199 14609 SANDWICH - 1, PLANO, SP, 1113 ACSR 2024-01-012024-12-31 C000199 F24-HOMEWOOD, Distribution, Unattended 2024-12-31 C000199 Bank Fees 2024-01-012024-12-31 C000199 Docket No.  23-0773  Rider IMUD 2024-01-012024-12-31 C000199 7910 SPAULDING - 3, WAYNE, WP, 1113 ACSR 2024-01-012024-12-31 C000199 TSS 146 Sandwich 138kV Station 2024-01-012024-12-31 C000199 250-BARRINGTON HILLS, Distribution, Unattended 2024-12-31 C000199 B86-CLARE, Distribution, Unattended 2024-12-31 C000199 4611 DESPLAINES 46 - 2, GOLF MILL, SP, 1113 ACSR 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-252 Facilities Study926 2024-01-012024-12-31 C000199 Chicago-Northwestern R. R. 2024-01-012024-12-31 C000199 Long Term receivable from Constellation Energy Generation, LLC (formerly Exelon Generation Company, LLC) (SFAS 143, Regulatory Liability offset) 2023-12-31 C000199 149-WILMINGTON-2, Distribution, Unattended 2024-12-31 C000199 793-LARAMIE, Distribution, Unattended 2024-12-31 C000199 Interval Meter Usage Data 2024-01-012024-12-31 C000199 G81-BLUE ISLAND, Distribution, Unattended 2024-12-31 C000199 B48-RINK, Distribution, Unattended 2024-12-31 C000199 Cherry Valley-Silver Lake 2024-01-012024-12-31 C000199 129-NILES-1, Distribution, Unattended 2024-01-012024-12-31 C000199 F79-BLOOM TWP, Distribution, Unattended 2024-12-31 C000199 W64-TRI STATE-1, Distribution, Unattended 2024-12-31 C000199 514-GLEN ELLYN, Distribution, Unattended 2024-01-012024-12-31 C000199 113, 3.800% 2024-01-012024-12-31 C000199 SchedulePumpedStorageGeneratingPlantStatisticsAbstract 2024-01-012024-12-31 C000199 539-WARRENVILLE, Distribution, Unattended 2024-12-31 C000199 160-ALPINE-1, Distribution, Unattended 2024-12-31 C000199 917 W Fulton - Perm Serviceferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 BES H - Hourly 2024-01-012024-12-31 C000199 60-ALSIP-2, Distribution, Unattended 2024-01-012024-12-31 C000199 Other (provide details in footnote): 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-120 Facilities Study561.7 2024-01-012024-12-31 C000199 577-SOUTH ELGIN-1, Distribution, Unattended 2024-12-31 C000199 79-SPAULDING-2, Distribution, Unattended 2024-01-012024-12-31 C000199 90-DEKOVEN, Distribution, Unattended 2024-01-012024-12-31 C000199 Upgrade 345kV L97008ferc:ElectricUtilityMember 2024-12-31 C000199 C22-LINCOLNWOOD, Distribution, Unattended 2024-01-012024-12-31 C000199 Other 2023-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-319 Facilities Study921 2024-01-012024-12-31 C000199 GRIP 2016 12kV Y8256 2024-01-012024-12-31 C000199 Energy Transition Assistance Charge, Other Taxes, IL, 2024 2024-01-012024-12-31 C000199 90907 DEER CREEK - 2, BROKAW (AMEREN), ST, 2-1277 ACAR 2024-01-012024-12-31 C000199 132-GARDEN PLAIN-2, Distribution, Unattended 2024-01-012024-12-31 C000199 Various complaint and petition matters 2024-01-012024-12-31 C000199 Apollo Boundary Apps Cl 2024-01-012024-12-31 C000199 123, 3.750% 2024-12-31 C000199 Information Technology, Baltimore Gas & Electric 2024-01-012024-12-31 C000199 TSS184 Elk Grove 345kV TR 81 2024-01-012024-12-31 C000199 TransAlta Energy Marketing (U.S.) Inc., OS, 2024-01-012024-12-31 C000199 PJM AF2-350921 2024-01-012024-12-31 C000199 145-YORK CENTER, Distribution, Unattended 2024-12-31 C000199 6607 EAST FRANKFORT - 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2, EDWARD STA (CILCO), SP, 1113 ACSR 2024-01-012024-12-31 C000199 PJM AF2-226 Facilities Study408.1 2024-01-012024-12-31 C000199 PJM AG1-434 Facilities Study408.1 2024-01-012024-12-31 C000199 F36-GOODENOW, Distribution, Unattended 2024-01-012024-12-31 C000199 Other Projects - 3 2024-01-012024-12-31 C000199 G30-CALUMET CITY, Distribution, Unattended 2024-01-012024-12-31 C000199 11622 GOODINGS GROVE - 1, ELWOOD, ST, 2156 ACSR 2024-01-012024-12-31 C000199 D99-FRANKLIN PARK-2, Distribution, Unattended 2024-01-012024-12-31 C000199 75-CRYSTAL LAKE-2, Distribution, Unattended 2024-01-012024-12-31 C000199 C30-LAKE FOREST, Distribution, Unattended 2024-12-31 C000199 0321 POWERTON - 2, TOULON, SP, 1113 ACSR, 922 2024-01-012024-12-31 C000199 Rate Case 2023-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-441 Facilities Study921 2024-01-012024-12-31 C000199 18-WILL COUNTY, Distribution, Attended 2024-12-31 C000199 5P220402 Boring D3427 feeder 2024-01-012024-12-31 C000199 Docket No.  docket anticipated  Value of DER 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember AF2-349 Garden Prairie 345 kV926 2024-01-012024-12-31 C000199 11418 NORTHWEST, CROSBY, SP, 266.8 ACSR 2024-01-012024-12-31 C000199 5104 MCCOOK - 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2, BRAIDWOOD, ST, 2-1277 ACAR 2024-01-012024-12-31 C000199 G113-HARVEY, Distribution, Unattended 2024-12-31 C000199 30-COLUMBUS PARK-1, Distribution, Unattended 2024-01-012024-12-31 C000199 Auto Transformers at TSS192 2024-01-012024-12-31 C000199 TSS 181 Compass Data Center 2024-01-012024-12-31 C000199 PJM AF2-394 Facilities Study926 2024-01-012024-12-31 C000199 7306 CHICAGO HTS. - 3, BLOOM, WP, 1113 ACSR 2024-01-012024-12-31 C000199 Apollo Boundary Apps Clferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 B10-HARVARD, Distribution, Unattended 2024-12-31 C000199 STREAM 1 ADD SERVICE 2024-01-012024-12-31 C000199 162-PIERPONT-2, Distribution, Unattended 2024-01-012024-12-31 C000199 Coal to Solar 2024-01-012024-12-31 C000199 Other Projects 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-142 Facilities Study408.1 2024-01-012024-12-31 C000199 Rochelle Franchise Fees to be amortized through 2070 2024-01-012024-12-31 C000199 ScheduleCommonUtilityPlantAndExpensesAbstract 2024-01-012024-12-31 C000199 Y302-27TH STREET, Distribution, Unattended 2024-01-012024-12-31 C000199 RDS - Delivery Service 2024-01-012024-12-31 C000199 H65-PLANO, Distribution, Unattended 2024-12-31 C000199 W340-WEISBROOK, Distribution, Unattended 2024-01-012024-12-31 C000199 557-BUTTERFIELD, Distribution, Unattended 2024-12-31 C000199 85-SKOKIE, Distribution, Unattended 2024-01-012024-12-31 C000199 14818 WEST LOOP, DIVERSEY, UG, 1600 MM2 XLPE 2024-01-012024-12-31 C000199 AF2-143 Powerton- Nevada 345kV926 2024-01-012024-12-31 C000199 PJM AF2-363 Cherry Valley-Glid926 2024-01-012024-12-31 C000199 Wayne-Itascaferc:LandAndRightsMember 2024-12-31 C000199 2019 REACTS TSS86 to TSS946 BBferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 5811 MADISON, GRAND, UG, 1600 MM2 XLPE 2024-01-012024-12-31 C000199 0ferc:OtherInvestmentsInSubsidiaryCompaniesMember 2024-12-31 C000199 0ferc:UnspecifiedInvestmentsInSubsidiaryCompaniesOneMember 2023-12-31 C000199 Chicago Use Tax, Sales And Use Tax, IL, 2024ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 NRG Power Marketing, LLC, OS, 2024-01-012024-12-31 C000199 146-SANDWICH, Distribution, Unattended 2024-12-31 C000199 W115-GLENWOOD PARK, Distribution, Unattended 2024-01-012024-12-31 C000199 Uncollectible Accounts Expense - 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(JOLIET), Distribution, Unattended 2024-12-31 C000199 ferc:ElectricUtilityMember 3% 2024-01-012024-12-31 C000199 E22-WAUCONDA, Distribution, Unattended 2024-12-31 C000199 1205 DRESDEN - 2, SW TIE L-0108, WP, 477,1113 ACSR 2024-01-012024-12-31 C000199 101-ITASCA, Distribution, Unattended 2024-12-31 C000199 AF2-027 Facility Study408.1 2024-01-012024-12-31 C000199 10118 ITASCA - 1, TONNE, SP, 2156 ACSR 2024-01-012024-12-31 C000199 PJM AF1-030 Facility Study926 2024-01-012024-12-31 C000199 391-ARGYLE, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-201 Facilities Study561.7 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AG1-005 Facilities Study561.7 2024-01-012024-12-31 C000199 K18-MOMENCE, Distribution, Unattended 2024-01-012024-12-31 C000199 10302 LISLE - 2, LOMBARD, SP, 1113,2156,2-1113A 2024-01-012024-12-31 C000199 G128-MARKHAM-1, Distribution, Unattended 2024-12-31 C000199 5118 MCCOOK - 2, BELLWOOD, ST, 1113 AA / 1113 AC 2024-01-012024-12-31 C000199 REACTS1C224303 TDC714-TDC714-2 2024-01-012024-12-31 C000199 1 items less than $250,000ferc:OtherPropertyMember 2024-01-012024-12-31 C000199 C33-NILES-2, Distribution, Unattended 2024-12-31 C000199 C82-HIGHLAND PARK, Distribution, Unattended 2024-12-31 C000199 B63-LANARK, Distribution, Unattended 2024-12-31 C000199 Wayne-Itascaferc:LandAndRightsMember 2024-01-012024-12-31 C000199 525-NORMANTOWN, Distribution, Unattended 2024-01-012024-12-31 C000199 Edged Energy Data Center - ESSferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 Aligned ESS at Elk Grove 2024-01-012024-12-31 C000199 Dividends declared 2024-01-012024-12-31 C000199 ferc:OtherTaxMember 2024-12-31 C000199 13501 ELMHURST - 3, BELLWOOD, WP, 900,1113 ACSR 2024-01-012024-12-31 C000199 Cook County Forest Preserve District License Fees to be amortized through 2027 2024-12-31 C000199 Underground Line Expenses, , , 2024-01-012024-12-31 C000199 X319-UPTOWN, Distribution, Unattended 2024-01-012024-12-31 C000199 115-BEDFORD PARK, Distribution, Unattended 2024-12-31 C000199 PJM AF1-253 Facilities Study561.7 2024-01-012024-12-31 C000199 51-MCCOOK-1, Transmission, Attended 2024-12-31 C000199 150-CALUMET-1, Distribution, Attended 2024-01-012024-12-31 C000199 PJM MISO J955 FACILITIES STUDY926 2024-01-012024-12-31 C000199 C61-GARNETT, Distribution, Unattended 2024-01-012024-12-31 C000199 69-NORTH CHICAGO-1, Distribution, Unattended 2024-12-31 C000199 SPARE TRANSFORMER-6, , 2024-01-012024-12-31 C000199 15625 CHERRY VALLEY - 1, WEMPLETOWN, ST, 1113,2156 ACSR 2024-01-012024-12-31 C000199 Non AMI Meters 2024-01-012024-12-31 C000199 8806 SKOKIE 88 - 1, NORTHBROOK 159, ST, 1113 ACSR 2024-01-012024-12-31 C000199 GIS Transmission SWferc:ElectricUtilityMember 2024-12-31 C000199 Insurance Contributions (FICA), Payroll Tax, Fed, 2024 2024-01-012024-12-31 C000199 8802 SKOKIE 88 - 2, GOLF MILL, SP, 1113 ACSR 2024-01-012024-12-31 C000199 5P230001 TSS131 Bus Expferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 452-GLENWOOD, Distribution, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-096 Facilities Study408.1 2024-01-012024-12-31 C000199 PJM AE2-341 Facility Study921 2024-01-012024-12-31 C000199 574-BARTLETT, Distribution, Unattended 2024-01-012024-12-31 C000199 Wilton Center-Joliet 2024-01-012024-12-31 C000199 13503 ELMHURST - 1, NORTHLAKE, ST, 900,1113 ACSR 2024-01-012024-12-31 C000199 1-LASALLE, Transmission, Attended 2024-01-012024-12-31 C000199 64-BELLWOOD-1, Distribution, Unattended 2024-12-31 C000199 162-PIERPONT-1, Distribution, Unattended 2024-01-012024-12-31 C000199 B35-COLETA, Distribution, Unattended 2024-12-31 C000199 12-DRESDEN-1, Transmission, Unattended 2024-01-012024-12-31 C000199 8221 CROSBY - 2, ROCKWELL, SP, 1113 ACSR 2024-01-012024-12-31 C000199 Plato Center - 2ferc:OtherPropertyMember 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-253 Facilities Study561.7 2024-01-012024-12-31 C000199 1P250200-New fdr to rlv TSS84ferc:ElectricUtilityMember 2024-12-31 C000199 H25-STERLING, Distribution, Unattended 2024-01-012024-12-31 C000199 144-WAYNE, Transmission, Unattended 2024-01-012024-12-31 C000199 G42-WORTH-2, Distribution, Unattended 2024-01-012024-12-31 C000199 Regulatory Governmental Affairs - Indirect, Exelon BSC 2024-01-012024-12-31 C000199 oneMDS Mobile Dispatch SW RL4ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 14106 PLEASANT VALLEY - 1, WOODSTOCK, WP, 664.8 ACSS/TW 2024-01-012024-12-31 C000199 15621 CHERRY VALLEY - 2, DIXON, SP, 1113 ACSR 2024-01-012024-12-31 C000199 Y365-CAMPBELL, Distribution, Unattended 2024-12-31 C000199 Sales Tax, Sales And Use Tax, IL, 2024 2024-01-012024-12-31 C000199 5107 MCCOOK - 1, RIDGELAND, ST, 1033.5ACSS/TW, 2- 2024-01-012024-12-31 C000199 798-CARROLL, Distribution, Unattended 2024-12-31 C000199 Uncollectible Accounts Expense - Under Recovery 2023-12-31 C000199 PJM AE2-173: MCLEAN 345 KV926 2024-01-012024-12-31 C000199 6608 EAST FRANKFORT - 2, UNIVERSITY PARK N.  E.C., SP, 1414 ACSR 2024-01-012024-12-31 C000199 15626 CHERRY VALLEY - 1, SABROOKE, ST, 1113 ACSR 2024-01-012024-12-31 C000199 137, 5.650% 2024-01-012024-12-31 C000199 Attachment H-13A of PJM of OATT - Revised, Docket No. ER 23-954-000 2024-01-012024-12-31 C000199 TSS 116 Goodings Grove - Instaferc:ElectricUtilityMember 2024-12-31 C000199 ferc:GenerationStudiesMember PJM AF1-030 Facility Study408.1 2024-01-012024-12-31 C000199 H36-YORKTOWN, Distribution, Unattended 2024-01-012024-12-31 C000199 D47-BROADVIEW-2, Distribution, Unattended 2024-12-31 C000199 W346-ADDISON TWP, Distribution, Unattended 2024-12-31 C000199 207-TONNE-2, Distribution, Unattended 2024-01-012024-12-31 C000199 W118-KENDALL TWP, Distribution, Unattended 2024-12-31 C000199 W349-BENSENVILLE, Distribution, Unattended 2024-12-31 C000199 1811 WILL COUNTY - 1, GOODINGS GROVE, ST, 900 ACSR 2024-01-012024-12-31 C000199 Requirement Sales:, , 2024-01-012024-12-31 C000199 9503 CHESTNUT - 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2, ELK GROVE, SP, 1113,2156 ACSR 2024-01-012024-12-31 C000199 Z335-SOUTH CHICAGO, Distribution, Unattended 2024-12-31 C000199 C85-NORTHBROOK-2, Distribution, Unattended 2024-12-31 C000199 Environmental remediation expenses 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember AF2-143 Powerton- Nevada 345kV926 2024-01-012024-12-31 C000199 AF2-349 Garden Prairie 345 kV408.1 2024-01-012024-12-31 C000199 Indirects-Removal for Budget 2024-01-012024-12-31 C000199 139-MENDOTA, Distribution, Unattended 2024-01-012024-12-31 C000199 101-ITASCA-2, Distribution, Unattended 2024-01-012024-12-31 C000199 16-WAUKEGAN-2, Distribution, Attended 2024-12-31 C000199 20090601-0016, 39948, ER09-1145-000 2024-01-012024-12-31 C000199 3P211002-56TH144 12 KV CONVferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 B64-FRANKLIN GROVE, Distribution, Unattended 2024-01-012024-12-31 C000199 D62-HILLSIDE, Distribution, Unattended 2024-01-012024-12-31 C000199 D292-OAK PARK, Distribution, Unattended 2024-01-012024-12-31 C000199 1210 DRESDEN - 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2, ARGONNE NAT'L LAB, WP, 1113 ACSR 2024-01-012024-12-31 C000199 D172-LAGRANGE, Distribution, Unattended 2024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-034 Facilities Study561.7 2024-01-012024-12-31 C000199 167-PLANO-2, Transmission, Unattended 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AF2-366 Facilities Study408.1 2024-01-012024-12-31 C000199 7P230800 - B169ferc:ElectricUtilityMember 2024-12-31 C000199 77698:7P230001-TSS113 UPG Distferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 AMI Meter Accelerated Depreciation 2024-01-012024-12-31 C000199 J69-BRAIDWOOD, Distribution, Unattended 2024-12-31 C000199 D187-MAYWOOD-2, Distribution, Unattended 2024-12-31 C000199 0ferc:CaptialStockMember 2024-01-012024-12-31 C000199 471-PONTIAC, Distribution, Unattended 2024-01-012024-12-31 C000199 666-CENTER, Distribution, Unattended 2024-12-31 C000199 Rochelle Franchise Fees to be amortized through 2070 2023-12-31 C000199 13304 ROCK FALLS, SCHAUFF ROAD, SP, 2-556.5, 2156ACSR 2024-01-012024-12-31 C000199 R14-NORTH, Distribution, Unattended 2024-01-012024-12-31 C000199 PJM AF1-253 Facilities Study408.1 2024-01-012024-12-31 C000199 Docket No. 23-0055 Verified Petition for Approval of a Multi-Year Rate Plan - amortized over 4 years (2024-2027) 2023-12-31 C000199 Other Accounts (Specify, details in footnote):ferc:ElectricPlantInServiceMemberferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 0303 POWERTON - 2, NEVADA, ST, 2-1277 ACAR 2024-01-012024-12-31 C000199 2022-12-31 C000199 D53-MAYWOOD, Distribution, Unattended 2024-12-31 C000199 2023-01-012023-12-31 C000199 G126-DOLTON, Distribution, Unattended 2024-12-31 C000199 PJM AG1-460 Facilities Study561.7 2024-01-012024-12-31 C000199 106-MONTGOMERY-1, Distribution, Unattended 2024-12-31 C000199 G121-WORTH, Distribution, Unattended 2024-12-31 C000199 G81-BLUE ISLAND, Distribution, Unattended 2024-01-012024-12-31 C000199 B86-CLARE, Distribution, Unattended 2024-01-012024-12-31 C000199 Cash Flow Swap Settlement Costs 2024-12-31 C000199 17907 DAVIS CREEK - 4, BLOOM, ST, T2-1113 ACSR 2024-01-012024-12-31 C000199 PJM AG1-298 Facilities Study921 2024-01-012024-12-31 C000199 109-APTAKISIC, Distribution, Unattended 2024-01-012024-12-31 C000199 REACTS 1C224302 TSS30-TSS38-01 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM AE2-223 McLean 345kV Facil926 2024-01-012024-12-31 C000199 406-NEW LENOX, Distribution, Unattended 2024-01-012024-12-31 C000199 TSS 76 Blue Island 345 kV Expa 2024-01-012024-12-31 C000199 ferc:GenerationStudiesMember PJM J982 Facilities Study408.1 2024-01-012024-12-31 C000199 L19414 S. Pecatonic breakferc:ElectricUtilityMember 2024-12-31 C000199 0ferc:UnspecifiedInvestmentsInSubsidiaryCompaniesThreeMember 2024-01-012024-12-31 C000199 SPARE TRANSFORMER-8, , 2024-12-31 C000199 H51-INDIAN CREEK, Distribution, Unattended 2024-12-31 C000199 122-BELVIDERE-2, Distribution, Unattended 2024-01-012024-12-31 C000199 135, 5.300% 2024-12-31 C000199 12004 LOMBARD, ELMHURST, ST, 2156 ACSR, 2338 ACAR, 2-664.8 ACSS/TW 2024-01-012024-12-31 C000199 11701 PROSPECT HTS - 2, DES PLAINES 46, ST, 1113 ACSR 2024-01-012024-12-31 C000199 GRIP 2016 12kV Y8256ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 318-HARVARD, Distribution, Unattended 2024-12-31 C000199 ferc:AprilMember 0 2024-01-012024-12-31 C000199 BES - Fixed 2024-01-012024-12-31 C000199 W335-WEST CHICAGO-1, Distribution, Unattended 2024-12-31 C000199 8809 SKOKIE 88 - 2, DEVON, SP, 1113 ACSR 2024-01-012024-12-31 C000199 F115-THORNTON, Distribution, Unattended 2024-12-31 C000199 PJM AF2-183- Nelson Lee County926 2024-01-012024-12-31 C000199 J81-BELLE AV, Distribution, Unattended 2024-12-31 C000199 PJM AG1-120 Facilities Study926 2024-01-012024-12-31 C000199 Federal Income Tax, Income Tax, Fed, 2024ferc:ElectricUtilityMember 2024-01-012024-12-31 C000199 33-HAYFORD, Distribution, Unattended 2024-12-31 C000199 C97-PARK RIDGE, Distribution, Unattended 2024-12-31 C000199 0, 0 2024-01-012024-12-31 iso4217:USD xbrli:shares utr:MW utr:kV iso4217:USD utr:kWh utr:MVA iso4217:USD utr:kWh xbrli:pure utr:mi xbrli:shares utr:MWh xbrli:pure utr:mi
THIS FILING IS
Item 1:
An Initial (Original) Submission
OR
Resubmission No.

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report

These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature
Exact Legal Name of Respondent (Company)

Commonwealth Edison Company
Year/Period of Report

End of:
2024
/
Q4


INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

  1. Purpose

    FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q) is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms.
  2. Who Must Submit

    Each Major electric utility, licensee, or other, as classified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities, Licensees, and Others Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).

    Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following:
    1. one million megawatt hours of total annual sales,
    2. 100 megawatt hours of annual sales for resale,
    3. 500 megawatt hours of annual power exchanges delivered, or
    4. 500 megawatt hours of annual wheeling for others (deliveries plus losses).
  3. What and Where to Submit

    1. Submit FERC Form Nos. 1 and 3-Q electronically through the eCollection portal at https://eCollection.ferc.gov, and according to the specifications in the Form 1 and 3-Q taxonomies.
    2. The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
    3. Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at:
      Secretary
      Federal Energy Regulatory Commission 888 First Street, NE
      Washington, DC 20426
    4. For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above.

      The CPA Certification Statement should:
      1. Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and
      2. Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.)

        Schedules
        Pages
        Comparative Balance Sheet 110-113
        Statement of Income 114-117
        Statement of Retained Earnings 118-119
        Statement of Cash Flows 120-121
        Notes to Financial Statements 122-123
    5. The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.

      “In connection with our regular examination of the financial statements of [COMPANY NAME] for the year ended on which we have reported separately under date of [DATE], we have also reviewed schedules [NAME OF SCHEDULES] of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.

      Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist.
    6. Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. Further instructions are found on the Commission’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-efilingferc-online.
    7. Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from https://www.ferc.gov/general-information-0/electric-industry-forms.
  4. When to Submit

    FERC Forms 1 and 3-Q must be filed by the following schedule:

    1. FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1), and
    2. FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400).
  5. Where to Send Comments on Public Reporting Burden.

    The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,168 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 168 hours per response.

    Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

GENERAL INSTRUCTIONS

  1. Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA.
  2. Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
  3. Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
  4. For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
  5. Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below).
  6. Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
  7. For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.
  8. Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
  9. Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
  10. Schedule specific instructions are found in the applicable taxonomy and on the applicable blank rendered form.
Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:

FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and” firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and “firm” means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions.

OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry.

AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment.

DEFINITIONS
  1. Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
  2. Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made.

EXCERPTS FROM THE LAW

Federal Power Act, 16 U.S.C. § 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:

  1. ’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
  2. 'Person' means an individual or a corporation;
  3. 'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof;
  1. 'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ......
  1. "project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered
  1. 'To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act."

"Sec. 304.
  1. Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may by rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports shall be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.10
"Sec. 309.
  1. The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field..."

GENERAL PENALTIES

The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).


FERC FORM NO.
1

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER
IDENTIFICATION
01 Exact Legal Name of Respondent

Commonwealth Edison Company
02 Year/ Period of Report


End of:
2024
/
Q4
03 Previous Name and Date of Change (If name changed during year)

/
04 Address of Principal Office at End of Period (Street, City, State, Zip Code)

10 S. Dearborn Street, Chicago, Illinois 60603
05 Name of Contact Person

Caroline Fulginiti
06 Title of Contact Person

Vice President and Assistant Controller, Exelon
07 Address of Contact Person (Street, City, State, Zip Code)

2301 Market Street, Philadelphia, Pennsylvania, 19103
08 Telephone of Contact Person, Including Area Code

(215) 841-5790
09 This Report is An Original / A Resubmission

(1)
An Original

(2)
A Resubmission
10 Date of Report (Mo, Da, Yr)

12/31/2024
Annual Corporate Officer Certification
The undersigned officer certifies that:

I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.

01 Name

Joshua S. Levin
02 Title

SVP, CFO and Treasurer
03 Signature

Joshua S. Levin
04 Date Signed (Mo, Da, Yr)

03/26/2025
Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
LIST OF SCHEDULES (Electric Utility)

Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".

Line No.
Title of Schedule
(a)
Reference Page No.
(b)
Remarks
(c)
ScheduleIdentificationAbstract
Identification
1
ScheduleListOfSchedulesAbstract
List of Schedules
2
1
ScheduleGeneralInformationAbstract
General Information
101
2
ScheduleControlOverRespondentAbstract
Control Over Respondent
102
3
ScheduleCorporationsControlledByRespondentAbstract
Corporations Controlled by Respondent
103
4
ScheduleOfficersAbstract
Officers
104
5
ScheduleDirectorsAbstract
Directors
105
6
ScheduleInformationOnFormulaRatesAbstract
Information on Formula Rates
106
7
ScheduleImportantChangesDuringTheQuarterYearAbstract
Important Changes During the Year
108
8
ScheduleComparativeBalanceSheetAbstract
Comparative Balance Sheet
110
9
ScheduleStatementOfIncomeAbstract
Statement of Income for the Year
114
10
ScheduleRetainedEarningsAbstract
Statement of Retained Earnings for the Year
118
12
ScheduleStatementOfCashFlowsAbstract
Statement of Cash Flows
120
12
ScheduleNotesToFinancialStatementsAbstract
Notes to Financial Statements
122
13
ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract
Statement of Accum Other Comp Income, Comp Income, and Hedging Activities
122a
14
ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep
200
15
ScheduleNuclearFuelMaterialsAbstract
Nuclear Fuel Materials
202
N/A
16
ScheduleElectricPlantInServiceAbstract
Electric Plant in Service
204
17
ScheduleElectricPropertyLeasedToOthersAbstract
Electric Plant Leased to Others
213
N/A
18
ScheduleElectricPlantHeldForFutureUseAbstract
Electric Plant Held for Future Use
214
19
ScheduleConstructionWorkInProgressElectricAbstract
Construction Work in Progress-Electric
216
20
ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract
Accumulated Provision for Depreciation of Electric Utility Plant
219
21
ScheduleInvestmentsInSubsidiaryCompaniesAbstract
Investment of Subsidiary Companies
224
22
ScheduleMaterialsAndSuppliesAbstract
Materials and Supplies
227
23
ScheduleAllowanceInventoryAbstract
Allowances
228
N/A
24
ScheduleExtraordinaryPropertyLossesAbstract
Extraordinary Property Losses
230a
N/A
25
ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract
Unrecovered Plant and Regulatory Study Costs
230b
N/A
26
ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract
Transmission Service and Generation Interconnection Study Costs
231
27
ScheduleOtherRegulatoryAssetsAbstract
Other Regulatory Assets
232
28
ScheduleMiscellaneousDeferredDebitsAbstract
Miscellaneous Deferred Debits
233
29
ScheduleAccumulatedDeferredIncomeTaxesAbstract
Accumulated Deferred Income Taxes
234
30
ScheduleCapitalStockAbstract
Capital Stock
250
31
ScheduleOtherPaidInCapitalAbstract
Other Paid-in Capital
253
32
ScheduleCapitalStockExpenseAbstract
Capital Stock Expense
254b
33
ScheduleLongTermDebtAbstract
Long-Term Debt
256
34
ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract
Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax
261
35
ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract
Taxes Accrued, Prepaid and Charged During the Year
262
36
ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract
Accumulated Deferred Investment Tax Credits
266
37
ScheduleOtherDeferredCreditsAbstract
Other Deferred Credits
269
38
ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract
Accumulated Deferred Income Taxes-Accelerated Amortization Property
272
N/A
39
ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract
Accumulated Deferred Income Taxes-Other Property
274
40
ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract
Accumulated Deferred Income Taxes-Other
276
41
ScheduleOtherRegulatoryLiabilitiesAbstract
Other Regulatory Liabilities
278
42
ScheduleElectricOperatingRevenuesAbstract
Electric Operating Revenues
300
43
ScheduleRegionalTransmissionServiceRevenuesAbstract
Regional Transmission Service Revenues (Account 457.1)
302
N/A
44
ScheduleSalesOfElectricityByRateSchedulesAbstract
Sales of Electricity by Rate Schedules
304
45
ScheduleSalesForResaleAbstract
Sales for Resale
310
46
ScheduleElectricOperationsAndMaintenanceExpensesAbstract
Electric Operation and Maintenance Expenses
320
47
SchedulePurchasedPowerAbstract
Purchased Power
326
48
ScheduleTransmissionOfElectricityForOthersAbstract
Transmission of Electricity for Others
328
49
ScheduleTransmissionOfElectricityByIsoOrRtoAbstract
Transmission of Electricity by ISO/RTOs
331
N/A
50
ScheduleTransmissionOfElectricityByOthersAbstract
Transmission of Electricity by Others
332
51
ScheduleMiscellaneousGeneralExpensesAbstract
Miscellaneous General Expenses-Electric
335
52
ScheduleDepreciationDepletionAndAmortizationAbstract
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
336
53
ScheduleRegulatoryCommissionExpensesAbstract
Regulatory Commission Expenses
350
54
ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract
Research, Development and Demonstration Activities
352
55
ScheduleDistributionOfSalariesAndWagesAbstract
Distribution of Salaries and Wages
354
56
ScheduleCommonUtilityPlantAndExpensesAbstract
Common Utility Plant and Expenses
356
N/A
57
ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract
Amounts included in ISO/RTO Settlement Statements
397
58
SchedulePurchasesSalesOfAncillaryServicesAbstract
Purchase and Sale of Ancillary Services
398
59
ScheduleMonthlyTransmissionSystemPeakLoadAbstract
Monthly Transmission System Peak Load
400
60
ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract
Monthly ISO/RTO Transmission System Peak Load
400a
N/A
61
ScheduleElectricEnergyAccountAbstract
Electric Energy Account
401a
62
ScheduleMonthlyPeakAndOutputAbstract
Monthly Peaks and Output
401b
63
ScheduleSteamElectricGeneratingPlantStatisticsAbstract
Steam Electric Generating Plant Statistics
402
N/A
64
ScheduleHydroelectricGeneratingPlantStatisticsAbstract
Hydroelectric Generating Plant Statistics
406
N/A
65
SchedulePumpedStorageGeneratingPlantStatisticsAbstract
Pumped Storage Generating Plant Statistics
408
N/A
66
ScheduleGeneratingPlantStatisticsAbstract
Generating Plant Statistics Pages
410
N/A
66.1
ScheduleEnergyStorageOperationsLargePlantsAbstract
Energy Storage Operations (Large Plants)
414
N/A
66.2
ScheduleEnergyStorageOperationsSmallPlantsAbstract
Energy Storage Operations (Small Plants)
419
N/A
67
ScheduleTransmissionLineStatisticsAbstract
Transmission Line Statistics Pages
422
68
ScheduleTransmissionLinesAddedAbstract
Transmission Lines Added During Year
424
N/A
69
ScheduleSubstationsAbstract
Substations
426
70
ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract
Transactions with Associated (Affiliated) Companies
429
71
FootnoteDataAbstract
Footnote Data
450
StockholdersReportsAbstract
Stockholders' Reports (check appropriate box)
Stockholders' Reports Check appropriate box:

Two copies will be submitted

No annual report to stockholders is prepared


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept.

Caroline Fulginiti

Vice President, Assistant Controller, Exelon

2 Lincoln Center, Oakbrook Terrace, Illinois 60181-4260
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized.

State of Incorporation:
IL

Date of Incorporation:
1913-10-17

Incorporated Under Special Law:

3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased.

Not applicable.

(a) Name of Receiver or Trustee Holding Property of the Respondent:

(b) Date Receiver took Possession of Respondent Property:

(c) Authority by which the Receivership or Trusteeship was created:

(d) Date when possession by receiver or trustee ceased:
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated.

Electric utility services in the State of Illinois.
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements?
(1)
Yes

(2)
No


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.
Exelon Corporation (Exelon) indirectly owns 99.99% of ComEd's common stock through Exelon's consolidated subsidiary Exelon Energy Delivery, LLC.


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
CORPORATIONS CONTROLLED BY RESPONDENT
  1. Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote.
  2. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved.
  3. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests.
Definitions
  1. See the Uniform System of Accounts for a definition of control.
  2. Direct control is that which is exercised without interposition of an intermediary.
  3. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control.
  4. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No.
NameOfCompanyControlledByRespondent
Name of Company Controlled
(a)
CompanyControlledByRespondentKindOfBusinessDescription
Kind of Business
(b)
VotingStockOwnedByRespondentPercentage
Percent Voting Stock Owned
(c)
FootnoteReferences
Footnote Ref.
(d)
1
Commonwealth Edison Company of Indiana, Inc.
Transmission of electricity
100
2
ComEd Financing III
Financing Trust
100
3
RITELine Illinois, LLC
Transmission of electricity
75
4
EdiSun, LLC
Development of solar panels
100


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
OFFICERS
  1. Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions.
  2. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No.
OfficerTitle
Title
(a)
OfficerName
Name of Officer
(b)
OfficerSalary
Salary for Year
(c)
DateOfficerIncumbencyStarted
Date Started in Period
(d)
DateOfficerIncumbencyEnded
Date Ended in Period
(e)
1
President and Chief Executive Officer
Gil Quiniones
632,678
2
Executive Vice President and Chief Operating Officer
David Perez
420,000
2024-01-01
3
Senior Vice President, Chief Financial Officer and Treasurer
Joshua Levin
386,250
4
Senior Vice President, Governmental, Regulatory and External Affairs
Lewis Binswanger
412,412
5
Senior Vice President, Customer Operations and Strategic Initiatives
Melissa Washington
370,452
6
Senior Vice President and General Counsel
E. Glenn Rippie
379,580
7
Corporate Secretary
Gayle Littleton
696,280
2024-12-31
8
Corporate Secretary
Colette Honorable
618,000
2025-01-01


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
DIRECTORS
  1. Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), name and abbreviated titles of the directors who are officers of the respondent.
  2. Provide the principle place of business in column (b), designate members of the Executive Committee in column (c), and the Chairman of the Executive Committee in column (d).
Line No.
NameAndTitleOfDirector
Name (and Title) of Director
(a)
PrincipalBusinessAddress
Principal Business Address
(b)
MemberOfTheExecutiveCommittee
Member of the Executive Committee
(c)
ChairmanOfTheExecutiveCommittee
Chairman of the Executive Committee
(d)
1
(a)
Michael Innocenzo
2301 Market Street, Philadelphia, PA 19101
true
true
2
(b)
Calvin G. Butler, Jr.
10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603
false
false
3
Gil Quiniones (Chief Executive Officer)
10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603
true
false
4
Ricardo Estrada
10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603
false
false
5
Zaldwaynaka Scott
10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603
false
false
6
Smita Shah
10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603
false
false
7
(c)
Elizabeth Buchanan
10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603
false
false
8
(d)
Stephen Bowman
10 S. Dearborn Street, 54th Floor, Chicago, Illinois 60603
false
false


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: NameAndTitleOfDirector
Effective April 1, 2024, Michael Innocenzo assumed the role of Director and Chairman of the Executive Committee.
(b) Concept: NameAndTitleOfDirector
Effective March 31, 2024, Calvin Butler resigned from his role as Director and Chairman of the Executive Committee.
(c) Concept: NameAndTitleOfDirector
Effective August 1, 2024, Elizabeth Buchanan assumed the role of Director.
(d) Concept: NameAndTitleOfDirector
Effective August 1, 2024, Stephen Bowman assumed the role of Director.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
INFORMATION ON FORMULA RATES
Does the respondent have formula rates?
Yes

No
  1. Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
Line No.
RateScheduleTariffNumber
FERC Rate Schedule or Tariff Number
(a)
ProceedingDocketNumber
FERC Proceeding
(b)
1
Attachment H-13A of PJM of OATT
Docket No. ER07-583-000
2
Attachment H-13A of PJM of OATT - Revised
Docket No. ER10-1247-000
3
Attachment H-13A of PJM of OATT - Revised
Docket No. ER11-3577-000
4
Attachment H-13A of PJM of OATT - Revised
Docket No. ER12-1793-000
5
Attachment H-13A of PJM of OATT - Revised
Docket No. ER13-1391-000
6
Attachment H-13A of PJM of OATT - Revised
Docket No. ER14-1203-000
7
Attachment H-13A of PJM of OATT - Revised
Docket No. ER14-1708-000
8
Attachment H-13A of PJM of OATT - Revised
Docket No. ER14-1728-000
9
Attachment H-13A of PJM of OATT - Revised
Docket No. ER15-959-000
10
Attachment H-13A of PJM of OATT - Revised
Docket No. ER15-1515-000
11
Attachment H-13A of PJM of OATT - Revised
Docket No. ER17-863-000
12
Attachment H-13A of PJM of OATT - Revised
Docket No. ER 19-5-000
13
Attachment H-13A of PJM of OATT - Revised
Docket No. ER 19-876-000
14
Attachment H-13A of PJM of OATT - Revised
Docket No. ER 19-1478-000
15
Attachment H-13A of PJM of OATT - Revised
Docket No. ER 22-1082-000
16
Attachment H-13A of PJM of OATT - Revised
Docket No. ER 23-954-000


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)?
Yes

No
  1. If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No.
AccessionNumber
Accession No.
(a)
DocumentDate
Document Date / Filed Date
(b)
DocketNumber
Docket No.
(c)
DescriptionOfFiling
Description
(d)
RateScheduleTariffNumber
Formula Rate FERC Rate Schedule Number or Tariff Number
(e)
1
05/15/2008
ER08-963-000
Formula Rate Annual Update
H-13 PJM OATT
2
05/15/2009
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
3
05/14/2010
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
4
05/16/2011
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
5
05/15/2012
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
6
04/29/2013
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
7
04/16/2014
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
8
04/15/2015
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
9
05/19/2015
ER09-1145-000
Formula Rate Annual Update - Correction
H-13 PJM OATT
10
04/13/2016
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
11
04/13/2017
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
12
05/04/2018
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
13
05/10/2019
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
14
05/15/2020
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
15
04/16/2021
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
16
04/29/2022
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
17
05/12/2023
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT
18
04/24/2024
ER09-1145-000
Formula Rate Annual Update
H-13 PJM OATT


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: AccessionNumber
Included within the formula rate filings are references to certain information included within the FERC Form 1 pages.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
INFORMATION ON FORMULA RATES - Formula Rate Variances
  1. If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1.
  2. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1.
  3. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts.
  4. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No.
PageNumberOfFormulaRateVariances
Page No(s).
(a)
ScheduleOfFormulaRateVariances
Schedule
(b)
ColumnOfFormulaRateVariances
Column
(c)
LineNumberOfFormulaRateVariances
Line No.
(d)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
IMPORTANT CHANGES DURING THE QUARTER/YEAR

Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears.

  1. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact.
  2. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization.
  3. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission.
  4. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization.
  5. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc.
  6. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee.
  7. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments.
  8. State the estimated annual effect and nature of any important wage scale changes during the year.
  9. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year.
  10. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest.
  11. (Reserved.)
  12. If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page.
  13. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period.
  14. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.
1. None.
2. None.
3. None.
4. None.
5. None.
6. Refer to Pages 122-123, Notes to Financial Statements: Note 10 — Debt and Credit Agreements for additional information on ComEd’s Debt and Credit activity in 2024 and back schedule pages 256-257 for discussion of ComEd’s long-term debt.

ComEd issues long-term debt under Orders by the Illinois Commerce Commission (ICC) approving ComEd’s securities. As of December 31, 2024, ComEd has New Money authority outstanding under Order 23-0492 totaling $1.8 billion and under Refinancing authority outstanding under Order 24-0104 totaling $500 million. On December 14, 2023, the ICC approved ComEd's request for $2.0 billion of New Money Authority, with an effective date of January 1, 2024, which will expire January 1, 2027. On February 20, 2024 ComEd Filed an application for $750 million in refinancing authority under Order 24-0104 from the ICC, which was approved on April 18, 2024. The refinancing authority under the approved application has an effective date of May 1, 2024, and extends the expiration date to May 1, 2027.

ComEd's commercial paper borrowings are issued under the authority of FERC order Docket No. ES24-4-000 for up to $2.5 billion of short-term debt over the course of two years. ComEd's short-term financing authority expires on December 31, 2025.
As of December 31, 2023, ComEd had an effective shelf registration statement unlimited in amount, filed with the SEC, that is set to expire on August 3, 2025. As of February 21, 2024, Exelon Corporation filed with the SEC a post-effective amendment to its shelf registration statement. As a result of the post-effective amendment, Exelon Corporation amended the existing shelf and is authorized to issue $7,200 million in securities. ComEd is listed as a co-registrant on the post-effective amendment filed with the SEC on February 21, 2024, and has the ability to issue a portion of the authorized Exelon Corporation amount in debt securities. There were no changes made to the August 3, 2025 expiration date of the shelf registration statement as a result of the post-effective amendment. ComEd’s ability to sell securities off the shelf registration statement or to access the private placement markets will depend on a number of factors at the time of the proposed sale, including other required regulatory approvals, as applicable, ComEd’s current financial condition, its securities ratings and market conditions.
7. None.
8. A base pay increase pool of 3% was distributed among exempt and non-exempt, non-represented employees on March 1, 2024 and 2025.
9. Refer to Pages 122-123, Notes to Financial Statements: Note 2 — Regulatory Matters and Note 12 - Commitments and Contingencies “Litigation and Regulatory Matters” section.
10. None.
12. None.
See Officers page (Page 104) and Directors page (Page 105) for details concerning changes in the respondent's officers and directors.
14. None.


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.
Title of Account
(a)
Ref. Page No.
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlant
Utility Plant (101-106, 114)
200
41,967,470,622
40,315,002,584
3
ConstructionWorkInProgress
Construction Work in Progress (107)
200
1,220,404,574
1,395,544,738
4
UtilityPlantAndConstructionWorkInProgress
TOTAL Utility Plant (Enter Total of lines 2 and 3)
43,187,875,196
41,710,547,322
5
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
(Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)
200
12,206,668,092
11,713,097,084
6
UtilityPlantNet
Net Utility Plant (Enter Total of line 4 less 5)
30,981,207,104
29,997,450,238
7
NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication
Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)
202
8
NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly
Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9
NuclearFuelAssembliesInReactorMajorOnly
Nuclear Fuel Assemblies in Reactor (120.3)
10
SpentNuclearFuelMajorOnly
Spent Nuclear Fuel (120.4)
11
NuclearFuelUnderCapitalLeases
Nuclear Fuel Under Capital Leases (120.6)
12
AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies
(Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)
202
13
NuclearFuelNet
Net Nuclear Fuel (Enter Total of lines 7-11 less 12)
14
UtilityPlantAndNuclearFuelNet
Net Utility Plant (Enter Total of lines 6 and 13)
30,981,207,104
29,997,450,238
15
OtherElectricPlantAdjustments
Utility Plant Adjustments (116)
16
GasStoredUndergroundNoncurrent
Gas Stored Underground - Noncurrent (117)
17
OtherPropertyAndInvestmentsAbstract
OTHER PROPERTY AND INVESTMENTS
18
NonutilityProperty
Nonutility Property (121)
9,697,258
9,697,258
19
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty
(Less) Accum. Prov. for Depr. and Amort. (122)
1,935,976
1,905,868
20
InvestmentInAssociatedCompanies
Investments in Associated Companies (123)
21
InvestmentInSubsidiaryCompanies
Investment in Subsidiary Companies (123.1)
224
106,206,800
102,288,128
23
NoncurrentPortionOfAllowances
Noncurrent Portion of Allowances
228
24
OtherInvestments
Other Investments (124)
43,427
37,334
25
SinkingFunds
Sinking Funds (125)
26
DepreciationFund
Depreciation Fund (126)
27
AmortizationFundFederal
Amortization Fund - Federal (127)
28
OtherSpecialFunds
Other Special Funds (128)
29
SpecialFunds
Special Funds (Non Major Only) (129)
30
DerivativeInstrumentAssetsLongTerm
Long-Term Portion of Derivative Assets (175)
31
DerivativeInstrumentAssetsHedgesLongTerm
Long-Term Portion of Derivative Assets - Hedges (176)
32
OtherPropertyAndInvestments
TOTAL Other Property and Investments (Lines 18-21 and 23-31)
114,011,509
110,116,852
33
CurrentAndAccruedAssetsAbstract
CURRENT AND ACCRUED ASSETS
34
CashAndWorkingFunds
Cash and Working Funds (Non-major Only) (130)
35
Cash
Cash (131)
17,224,016
45,643,539
36
SpecialDeposits
Special Deposits (132-134)
485,877,839
401,566,878
37
WorkingFunds
Working Fund (135)
38
TemporaryCashInvestments
Temporary Cash Investments (136)
39,423,613
23,989,634
39
NotesReceivable
Notes Receivable (141)
40
CustomerAccountsReceivable
Customer Accounts Receivable (142)
659,142,561
508,571,219
41
OtherAccountsReceivable
Other Accounts Receivable (143)
281,592,347
242,277,627
42
AccumulatedProvisionForUncollectibleAccountsCredit
(Less) Accum. Prov. for Uncollectible Acct.-Credit (144)
143,245,638
86,250,851
43
NotesReceivableFromAssociatedCompanies
Notes Receivable from Associated Companies (145)
44
AccountsReceivableFromAssociatedCompanies
Accounts Receivable from Assoc. Companies (146)
528,228
70,491
45
FuelStock
Fuel Stock (151)
227
46
FuelStockExpensesUndistributed
Fuel Stock Expenses Undistributed (152)
227
47
Residuals
Residuals (Elec) and Extracted Products (153)
227
48
PlantMaterialsAndOperatingSupplies
Plant Materials and Operating Supplies (154)
227
297,689,734
285,561,287
49
Merchandise
Merchandise (155)
227
50
OtherMaterialsAndSupplies
Other Materials and Supplies (156)
227
51
NuclearMaterialsHeldForSale
Nuclear Materials Held for Sale (157)
202/227
52
AllowanceInventoryAndWithheld
Allowances (158.1 and 158.2)
228
53
NoncurrentPortionOfAllowances
(Less) Noncurrent Portion of Allowances
228
54
StoresExpenseUndistributed
Stores Expense Undistributed (163)
227
55
GasStoredCurrent
Gas Stored Underground - Current (164.1)
56
LiquefiedNaturalGasStoredAndHeldForProcessing
Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57
Prepayments
Prepayments (165)
115,572,656
102,590,569
58
AdvancesForGas
Advances for Gas (166-167)
59
InterestAndDividendsReceivable
Interest and Dividends Receivable (171)
12,699
10,540
60
RentsReceivable
Rents Receivable (172)
61
AccruedUtilityRevenues
Accrued Utility Revenues (173)
334,534,395
351,134,876
62
MiscellaneousCurrentAndAccruedAssets
Miscellaneous Current and Accrued Assets (174)
4,020,994
4,318,888
63
DerivativeInstrumentAssets
Derivative Instrument Assets (175)
64
DerivativeInstrumentAssetsLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets (175)
65
DerivativeInstrumentAssetsHedges
Derivative Instrument Assets - Hedges (176)
66
DerivativeInstrumentAssetsHedgesLongTerm
(Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67
CurrentAndAccruedAssets
Total Current and Accrued Assets (Lines 34 through 66)
2,092,373,444
1,879,484,697
68
DeferredDebitsAbstract
DEFERRED DEBITS
69
UnamortizedDebtExpense
Unamortized Debt Expenses (181)
103,067,099
99,782,409
70
ExtraordinaryPropertyLosses
Extraordinary Property Losses (182.1)
230a
71
UnrecoveredPlantAndRegulatoryStudyCosts
Unrecovered Plant and Regulatory Study Costs (182.2)
230b
72
OtherRegulatoryAssets
Other Regulatory Assets (182.3)
232
3,996,746,550
4,396,564,225
73
PreliminarySurveyAndInvestigationCharges
Prelim. Survey and Investigation Charges (Electric) (183)
74
PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges
Preliminary Natural Gas Survey and Investigation Charges 183.1)
75
OtherPreliminarySurveyAndInvestigationCharges
Other Preliminary Survey and Investigation Charges (183.2)
76
ClearingAccounts
Clearing Accounts (184)
56
325
77
TemporaryFacilities
Temporary Facilities (185)
78
MiscellaneousDeferredDebits
Miscellaneous Deferred Debits (186)
233
5,977,542,374
4,997,467,960
79
DeferredLossesFromDispositionOfUtilityPlant
Def. Losses from Disposition of Utility Plt. (187)
80
ResearchDevelopmentAndDemonstrationExpenditures
Research, Devel. and Demonstration Expend. (188)
352
81
UnamortizedLossOnReacquiredDebt
Unamortized Loss on Reaquired Debt (189)
14,839,627
16,424,002
82
AccumulatedDeferredIncomeTaxes
Accumulated Deferred Income Taxes (190)
234
871,112,133
1,006,863,343
83
UnrecoveredPurchasedGasCosts
Unrecovered Purchased Gas Costs (191)
84
DeferredDebits
Total Deferred Debits (lines 69 through 83)
10,963,307,727
10,517,102,264
85
AssetsAndOtherDebits
TOTAL ASSETS (lines 14-16, 32, 67, and 84)
44,150,899,784
42,504,154,051


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.
Title of Account
(a)
Ref. Page No.
(b)
Current Year End of Quarter/Year Balance
(c)
Prior Year End Balance 12/31
(d)
1
ProprietaryCapitalAbstract
PROPRIETARY CAPITAL
2
CommonStockIssued
Common Stock Issued (201)
250
1,587,297,245
1,587,297,032
3
PreferredStockIssued
Preferred Stock Issued (204)
250
4
CapitalStockSubscribed
Capital Stock Subscribed (202, 205)
5
StockLiabilityForConversion
Stock Liability for Conversion (203, 206)
6
PremiumOnCapitalStock
Premium on Capital Stock (207)
5,020,105,353
5,020,104,944
7
OtherPaidInCapital
Other Paid-In Capital (208-211)
253
5,615,312,040
5,388,756,067
8
InstallmentsReceivedOnCapitalStock
Installments Received on Capital Stock (212)
252
9
DiscountOnCapitalStock
(Less) Discount on Capital Stock (213)
254
10
CapitalStockExpense
(Less) Capital Stock Expense (214)
254b
6,942,925
6,942,925
11
RetainedEarnings
Retained Earnings (215, 215.1, 216)
118
2,608,976,284
2,327,289,291
12
UnappropriatedUndistributedSubsidiaryEarnings
Unappropriated Undistributed Subsidiary Earnings (216.1)
118
60,499,848
51,743,312
13
ReacquiredCapitalStock
(Less) Reacquired Capital Stock (217)
250
14
NoncorporateProprietorship
Noncorporate Proprietorship (Non-major only) (218)
15
AccumulatedOtherComprehensiveIncome
Accumulated Other Comprehensive Income (219)
122(a)(b)
16
ProprietaryCapital
Total Proprietary Capital (lines 2 through 15)
14,885,247,845
14,368,247,721
17
LongTermDebtAbstract
LONG-TERM DEBT
18
Bonds
Bonds (221)
256
12,153,600,000
11,603,600,000
19
ReacquiredBonds
(Less) Reacquired Bonds (222)
256
20
AdvancesFromAssociatedCompanies
Advances from Associated Companies (223)
256
206,186,000
206,186,000
21
OtherLongTermDebt
Other Long-Term Debt (224)
256
22
UnamortizedPremiumOnLongTermDebt
Unamortized Premium on Long-Term Debt (225)
23
UnamortizedDiscountOnLongTermDebtDebit
(Less) Unamortized Discount on Long-Term Debt-Debit (226)
30,683,580
28,371,972
24
LongTermDebt
Total Long-Term Debt (lines 18 through 23)
12,329,102,420
11,781,414,028
25
OtherNoncurrentLiabilitiesAbstract
OTHER NONCURRENT LIABILITIES
26
ObligationsUnderCapitalLeaseNoncurrent
Obligations Under Capital Leases - Noncurrent (227)
7,475,353
7,532,029
27
AccumulatedProvisionForPropertyInsurance
Accumulated Provision for Property Insurance (228.1)
28
AccumulatedProvisionForInjuriesAndDamages
Accumulated Provision for Injuries and Damages (228.2)
120,642,632
81,424,515
29
AccumulatedProvisionForPensionsAndBenefits
Accumulated Provision for Pensions and Benefits (228.3)
191,071,720
197,131,365
30
AccumulatedMiscellaneousOperatingProvisions
Accumulated Miscellaneous Operating Provisions (228.4)
284,584,833
302,552,734
31
AccumulatedProvisionForRateRefunds
Accumulated Provision for Rate Refunds (229)
8,484,459
7,188,191
32
LongTermPortionOfDerivativeInstrumentLiabilities
Long-Term Portion of Derivative Instrument Liabilities
33
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
Long-Term Portion of Derivative Instrument Liabilities - Hedges
34
AssetRetirementObligations
Asset Retirement Obligations (230)
169,137,189
151,156,355
35
OtherNoncurrentLiabilities
Total Other Noncurrent Liabilities (lines 26 through 34)
781,396,186
746,985,189
36
CurrentAndAccruedLiabilitiesAbstract
CURRENT AND ACCRUED LIABILITIES
37
NotesPayable
Notes Payable (231)
35,995,450
601,937,997
38
AccountsPayable
Accounts Payable (232)
713,392,804
828,813,132
39
NotesPayableToAssociatedCompanies
Notes Payable to Associated Companies (233)
40
AccountsPayableToAssociatedCompanies
Accounts Payable to Associated Companies (234)
77,043,053
72,879,463
41
CustomerDeposits
Customer Deposits (235)
134,362,405
118,238,326
42
TaxesAccrued
Taxes Accrued (236)
262
95,223,579
211,291,922
43
InterestAccrued
Interest Accrued (237)
151,720,942
149,033,092
44
DividendsDeclared
Dividends Declared (238)
45
MaturedLongTermDebt
Matured Long-Term Debt (239)
46
MaturedInterest
Matured Interest (240)
47
TaxCollectionsPayable
Tax Collections Payable (241)
28,435,908
31,397,970
48
MiscellaneousCurrentAndAccruedLiabilities
Miscellaneous Current and Accrued Liabilities (242)
504,717,529
440,174,247
49
ObligationsUnderCapitalLeasesCurrent
Obligations Under Capital Leases-Current (243)
76,276
70,210
50
DerivativesInstrumentLiabilities
Derivative Instrument Liabilities (244)
51
LongTermPortionOfDerivativeInstrumentLiabilities
(Less) Long-Term Portion of Derivative Instrument Liabilities
52
DerivativeInstrumentLiabilitiesHedges
Derivative Instrument Liabilities - Hedges (245)
53
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges
(Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54
CurrentAndAccruedLiabilities
Total Current and Accrued Liabilities (lines 37 through 53)
1,740,967,946
2,453,836,359
55
DeferredCreditsAbstract
DEFERRED CREDITS
56
CustomerAdvancesForConstruction
Customer Advances for Construction (252)
781,908,871
455,558,952
57
AccumulatedDeferredInvestmentTaxCredits
Accumulated Deferred Investment Tax Credits (255)
266
6,278,126
6,810,301
58
DeferredGainsFromDispositionOfUtilityPlant
Deferred Gains from Disposition of Utility Plant (256)
59
OtherDeferredCredits
Other Deferred Credits (253)
269
116,180,770
120,260,137
60
OtherRegulatoryLiabilities
Other Regulatory Liabilities (254)
278
7,052,743,824
6,253,543,172
61
UnamortizedGainOnReacquiredDebt
Unamortized Gain on Reacquired Debt (257)
62
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty
Accum. Deferred Income Taxes-Accel. Amort.(281)
272
63
AccumulatedDeferredIncomeTaxesOtherProperty
Accum. Deferred Income Taxes-Other Property (282)
5,041,294,728
4,971,124,063
64
AccumulatedDeferredIncomeTaxesOther
Accum. Deferred Income Taxes-Other (283)
(a)
1,415,779,068
1,346,374,129
65
DeferredCredits
Total Deferred Credits (lines 56 through 64)
14,414,185,387
13,153,670,754
66
LiabilitiesAndOtherCredits
TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)
44,150,899,784
42,504,154,051


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxesOther
Description Beginning Balance Ending Balance
Pension Asset $ 347,053,474  $ 385,308,540 
Regulatory Asset 969,087,038  992,037,219 
Unamortized Loss on Required Debt 4,681,661  4,230,035 
Other 25,551,956  34,203,274 
Total $ 1,346,374,129  $ 1,415,779,068 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
STATEMENT OF INCOME

Quarterly

  1. Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only.
  2. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year.
  3. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter.
  4. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter.
  5. If additional columns are needed, place them in a footnote.

Annual or Quarterly if applicable

  1. Do not report fourth quarter data in columns (e) and (f)
  2. Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals.
  3. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above.
  4. Use page 122 for important notes regarding the statement of income for any account thereof.
  5. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases.
  6. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts.
  7. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122.
  8. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes.
  9. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports.
  10. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.
Title of Account
(a)
(Ref.) Page No.
(b)
Total Current Year to Date Balance for Quarter/Year
(c)
Total Prior Year to Date Balance for Quarter/Year
(d)
Current 3 Months Ended - Quarterly Only - No 4th Quarter
(e)
Prior 3 Months Ended - Quarterly Only - No 4th Quarter
(f)
Electric Utility Current Year to Date (in dollars)
(g)
Electric Utility Previous Year to Date (in dollars)
(h)
Gas Utiity Current Year to Date (in dollars)
(i)
Gas Utility Previous Year to Date (in dollars)
(j)
Other Utility Current Year to Date (in dollars)
(k)
Other Utility Previous Year to Date (in dollars)
(l)
1
UtilityOperatingIncomeAbstract
UTILITY OPERATING INCOME
2
OperatingRevenues
Operating Revenues (400)
300
8,163,984,950
7,847,450,785
8,163,984,950
7,847,450,785
3
OperatingExpensesAbstract
Operating Expenses
4
OperationExpense
Operation Expenses (401)
320
4,234,423,204
3,832,950,659
4,234,423,204
3,832,950,659
5
MaintenanceExpense
Maintenance Expenses (402)
320
492,900,321
459,380,558
492,900,321
459,380,558
6
DepreciationExpense
Depreciation Expense (403)
336
1,052,277,392
1,006,052,806
1,052,277,392
1,006,052,806
7
DepreciationExpenseForAssetRetirementCosts
Depreciation Expense for Asset Retirement Costs (403.1)
336
1,830,160
1,858,923
1,830,160
1,858,923
8
AmortizationAndDepletionOfUtilityPlant
Amort. & Depl. of Utility Plant (404-405)
336
129,435,286
100,660,161
129,435,286
100,660,161
9
AmortizationOfElectricPlantAcquisitionAdjustments
Amort. of Utility Plant Acq. Adj. (406)
336
10
AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts
Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11
AmortizationOfConversionExpenses
Amort. of Conversion Expenses (407.2)
12
RegulatoryDebits
Regulatory Debits (407.3)
346,966,972
305,964,625
346,966,972
305,964,625
13
RegulatoryCredits
(Less) Regulatory Credits (407.4)
(a)
118,650,816
(b)
62,177,236
118,650,816
62,177,236
14
TaxesOtherThanIncomeTaxesUtilityOperatingIncome
Taxes Other Than Income Taxes (408.1)
262
372,144,480
367,534,329
372,144,480
367,534,329
15
IncomeTaxesOperatingIncome
Income Taxes - Federal (409.1)
262
70,955,520
129,557,732
70,955,520
129,557,732
16
IncomeTaxesUtilityOperatingIncomeOther
Income Taxes - Other (409.1)
262
61,713,309
11,432,424
61,713,309
11,432,424
17
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome
Provision for Deferred Income Taxes (410.1)
234, 272
463,852,957
592,520,153
463,852,957
592,520,153
18
ProvisionForDeferredIncomeTaxesCreditOperatingIncome
(Less) Provision for Deferred Income Taxes-Cr. (411.1)
234, 272
488,297,479
399,639,434
488,297,479
399,639,434
19
InvestmentTaxCreditAdjustments
Investment Tax Credit Adj. - Net (411.4)
266
993,294
1,218,203
993,294
1,218,203
20
GainsFromDispositionOfPlant
(Less) Gains from Disp. of Utility Plant (411.6)
21
LossesFromDispositionOfServiceCompanyPlant
Losses from Disp. of Utility Plant (411.7)
22
GainsFromDispositionOfAllowances
(Less) Gains from Disposition of Allowances (411.8)
23
LossesFromDispositionOfAllowances
Losses from Disposition of Allowances (411.9)
24
AccretionExpense
Accretion Expense (411.10)
30,043
51,297
30,043
51,297
25
UtilityOperatingExpenses
TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)
6,618,588,055
6,322,063,946
6,618,588,055
6,322,063,946
27
NetUtilityOperatingIncome
Net Util Oper Inc (Enter Tot line 2 less 25)
1,545,396,895
1,525,386,839
1,545,396,895
1,525,386,839
28
OtherIncomeAndDeductionsAbstract
Other Income and Deductions
29
OtherIncomeAbstract
Other Income
30
NonutilityOperatingIncomeAbstract
Nonutilty Operating Income
31
RevenuesFromMerchandisingJobbingAndContractWork
Revenues From Merchandising, Jobbing and Contract Work (415)
77,031,423
22,794,716
32
CostsAndExpensesOfMerchandisingJobbingAndContractWork
(Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
77,606,927
22,319,615
33
RevenuesFromNonutilityOperations
Revenues From Nonutility Operations (417)
34
ExpensesOfNonutilityOperations
(Less) Expenses of Nonutility Operations (417.1)
35
NonoperatingRentalIncome
Nonoperating Rental Income (418)
36
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings of Subsidiary Companies (418.1)
119
9,149,347
5,517,419
37
InterestAndDividendIncome
Interest and Dividend Income (419)
23,310,870
22,029,291
38
AllowanceForOtherFundsUsedDuringConstruction
Allowance for Other Funds Used During Construction (419.1)
46,146,117
33,462,076
39
MiscellaneousNonoperatingIncome
Miscellaneous Nonoperating Income (421)
23,253,461
17,817,710
40
GainOnDispositionOfProperty
Gain on Disposition of Property (421.1)
41
OtherIncome
TOTAL Other Income (Enter Total of lines 31 thru 40)
101,284,291
79,301,597
42
OtherIncomeDeductionsAbstract
Other Income Deductions
43
LossOnDispositionOfProperty
Loss on Disposition of Property (421.2)
44
MiscellaneousAmortization
Miscellaneous Amortization (425)
45
Donations
Donations (426.1)
5,175,524
5,905,354
46
LifeInsurance
Life Insurance (426.2)
25,408
8,098
47
Penalties
Penalties (426.3)
621,319
1,168,760
48
ExpendituresForCertainCivicPoliticalAndRelatedActivities
Exp. for Certain Civic, Political & Related Activities (426.4)
3,978,809
5,200,212
49
OtherDeductions
Other Deductions (426.5)
63,209,847
16,614,085
50
OtherIncomeDeductions
TOTAL Other Income Deductions (Total of lines 43 thru 49)
71,768,269
28,880,313
51
TaxesApplicableToOtherIncomeAndDeductionsAbstract
Taxes Applic. to Other Income and Deductions
52
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions
Taxes Other Than Income Taxes (408.2)
262
2,503,180
956,149
53
IncomeTaxesFederal
Income Taxes-Federal (409.2)
262
2,979,344
6,753,836
54
IncomeTaxesOther
Income Taxes-Other (409.2)
262
2,385,084
1,295,297
55
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions
Provision for Deferred Inc. Taxes (410.2)
234, 272
5,403,183
56
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions
(Less) Provision for Deferred Income Taxes-Cr. (411.2)
234, 272
4,162,560
57
InvestmentTaxCreditAdjustmentsNonutilityOperations
Investment Tax Credit Adj.-Net (411.5)
58
InvestmentTaxCredits
(Less) Investment Tax Credits (420)
59
TaxesOnOtherIncomeAndDeductions
TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)
8,500,623
4,842,722
60
NetOtherIncomeAndDeductions
Net Other Income and Deductions (Total of lines 41, 50, 59)
21,015,399
45,578,562
61
InterestChargesAbstract
Interest Charges
62
InterestOnLongTermDebt
Interest on Long-Term Debt (427)
483,054,341
457,291,632
63
AmortizationOfDebtDiscountAndExpense
Amort. of Debt Disc. and Expense (428)
7,724,318
7,063,111
64
AmortizationOfLossOnReacquiredDebt
Amortization of Loss on Reaquired Debt (428.1)
1,584,375
1,584,375
65
AmortizationOfPremiumOnDebtCredit
(Less) Amort. of Premium on Debt-Credit (429)
66
AmortizationOfGainOnReacquiredDebtCredit
(Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67
InterestOnDebtToAssociatedCompanies
Interest on Debt to Assoc. Companies (430)
13,092,811
13,092,811
68
OtherInterestExpense
Other Interest Expense (431)
23,810,563
36,332,711
69
AllowanceForBorrowedFundsUsedDuringConstructionCredit
(Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)
28,941,211
38,477,582
70
NetInterestCharges
Net Interest Charges (Total of lines 62 thru 69)
500,325,197
476,887,058
71
IncomeBeforeExtraordinaryItems
Income Before Extraordinary Items (Total of lines 27, 60 and 70)
1,066,087,097
1,094,078,343
72
ExtraordinaryItemsAbstract
Extraordinary Items
73
ExtraordinaryIncome
Extraordinary Income (434)
74
ExtraordinaryDeductions
(Less) Extraordinary Deductions (435)
75
NetExtraordinaryItems
Net Extraordinary Items (Total of line 73 less line 74)
76
IncomeTaxesExtraordinaryItems
Income Taxes-Federal and Other (409.3)
262
77
ExtraordinaryItemsAfterTaxes
Extraordinary Items After Taxes (line 75 less line 76)
78
NetIncomeLoss
Net Income (Total of line 71 and 77)
1,066,087,097
1,094,078,343


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: RegulatoryCredits
Refer to Note 2 - Regulatory Matters of the Notes to Financial Statements located on page 122-123.
(b) Concept: RegulatoryCredits
Refer to Note 2 - Regulatory Matters of the Notes to Financial Statements located on page 122-123.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report


End of:
2024
/
Q4
STATEMENT OF RETAINED EARNINGS
  1. Do not report Lines 49-53 on the quarterly report.
  2. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year.
  3. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b).
  4. State the purpose and amount for each reservation or appropriation of retained earnings.
  5. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order.
  6. Show dividends for each class and series of capital stock.
  7. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings.
  8. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated.
  9. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.
Item
(a)
Contra Primary Account Affected
(b)
Current Quarter/Year Year to Date Balance
(c)
Previous Quarter/Year Year to Date Balance
(d)
UnappropriatedRetainedEarningsAbstract
UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1
UnappropriatedRetainedEarnings
Balance-Beginning of Period
1,689,302,284
1,684,177,676
2
ChangesAbstract
Changes
3
AdjustmentsToRetainedEarningsAbstract
Adjustments to Retained Earnings (Account 439)
4
AdjustmentsToRetainedEarningsCreditAbstract
Adjustments to Retained Earnings Credit
9
AdjustmentsToRetainedEarningsCredit
TOTAL Credits to Retained Earnings (Acct. 439)
10
AdjustmentsToRetainedEarningsDebitAbstract
Adjustments to Retained Earnings Debit
15
AdjustmentsToRetainedEarningsDebit
TOTAL Debits to Retained Earnings (Acct. 439)
16
BalanceTransferredFromIncome
Balance Transferred from Income (Account 433 less Account 418.1)
1,056,937,750
1,088,560,924
17
AppropriationsOfRetainedEarningsAbstract
Appropriations of Retained Earnings (Acct. 436)
17.1
AppropriationsOfRetainedEarnings
Transfer to appropriated retained earnings for payment of future dividends
1,066,087,097
1,094,078,343
22
AppropriationsOfRetainedEarnings
TOTAL Appropriations of Retained Earnings (Acct. 436)
1,066,087,097
1,094,078,343
23
DividendsDeclaredPreferredStockAbstract
Dividends Declared-Preferred Stock (Account 437)
29
DividendsDeclaredPreferredStock
TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30
DividendsDeclaredCommonStockAbstract
Dividends Declared-Common Stock (Account 438)
36
DividendsDeclaredCommonStock
TOTAL Dividends Declared-Common Stock (Acct. 438)
37
TransfersFromUnappropriatedUndistributedSubsidiaryEarnings
Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings
392,811
392,811
38
UnappropriatedRetainedEarnings
Balance - End of Period (Total 1,9,15,16,22,29,36,37)
1,698,058,820
1,689,302,284
39
AppropriatedRetainedEarningsAbstract
APPROPRIATED RETAINED EARNINGS (Account 215)
39.1
AppropriatedRetainedEarnings
Balance - Beginning of Year (Debit or Credit)
4,016,591,575
3,667,874,778
39.2
AppropriatedRetainedEarnings
Appropriations of retained earnings for future dividend payments
1,066,087,097
1,094,078,343
39.3
AppropriatedRetainedEarnings
Dividends declared
775,643,568
745,361,546
39.4
AppropriatedRetainedEarnings
Tax Adjustment for FIN48
45
AppropriatedRetainedEarnings
TOTAL Appropriated Retained Earnings (Account 215)
4,307,035,104
4,016,591,575
AppropriatedRetainedEarningsAmortizationReserveFederalAbstract
APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46
AppropriatedRetainedEarningsAmortizationReserveFederal
TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47
AppropriatedRetainedEarningsIncludingReserveAmortization
TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
4,307,035,104
4,016,591,575
48
RetainedEarnings
TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)
2,608,976,284
2,327,289,291
UnappropriatedUndistributedSubsidiaryEarningsAbstract
UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49
UnappropriatedUndistributedSubsidiaryEarnings
Balance-Beginning of Year (Debit or Credit)
51,743,312
46,618,704
50
EquityInEarningsOfSubsidiaryCompanies
Equity in Earnings for Year (Credit) (Account 418.1)
9,149,347
5,517,419
51
DividendsReceived
(Less) Dividends Received (Debit)
392,811
392,811
52
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits
TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53
UnappropriatedUndistributedSubsidiaryEarnings
Balance-End of Year (Total lines 49 thru 52)
60,499,848
51,743,312


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
STATEMENT OF CASH FLOWS
  1. Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc.
  2. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet.
  3. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid.
  4. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.
Description (See Instructions No.1 for explanation of codes)
(a)
Current Year to Date Quarter/Year
(b)
Previous Year to Date Quarter/Year
(c)
1
NetCashFlowFromOperatingActivitiesAbstract
Net Cash Flow from Operating Activities
2
NetIncomeLoss
Net Income (Line 78(c) on page 117)
1,066,087,097
1,094,078,343
3
NoncashChargesCreditsToIncomeAbstract
Noncash Charges (Credits) to Income:
4
DepreciationAndDepletion
Depreciation and Depletion
1,183,542,838
1,106,846,515
5
NoncashAdjustmentsToCashFlowsFromOperatingActivities
Amortization of (Specify) (footnote details)
5.1
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Amortization of Regulatory Debits
346,966,972
307,690,000
8
DeferredIncomeTaxesNet
Deferred Income Taxes (Net)
19,041,339
188,718,159
9
InvestmentTaxCreditAdjustmentsNet
Investment Tax Credit Adjustment (Net)
993,294
1,218,203
10
NetIncreaseDecreaseInReceivablesOperatingActivities
Net (Increase) Decrease in Receivables
164,328,725
91,686,824
11
NetIncreaseDecreaseInInventoryOperatingActivities
Net (Increase) Decrease in Inventory
12,128,447
82,594,953
12
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities
Net (Increase) Decrease in Allowances Inventory
13
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
210,496,077
149,791,921
14
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities
Net (Increase) Decrease in Other Regulatory Assets
109,980,587
1,203,735,116
15
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities
Net Increase (Decrease) in Other Regulatory Liabilities
283,556,370
566,474,926
16
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities
(Less) Allowance for Other Funds Used During Construction
46,146,117
33,462,076
17
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities
(Less) Undistributed Earnings from Subsidiary Companies
9,149,347
5,517,419
18
OtherAdjustmentsToCashFlowsFromOperatingActivities
Other (provide details in footnote):
18.1
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription
Other (provide details in footnote):
(a)
240,243,317
(c)
263,962,518
22
NetCashFlowFromOperatingActivities
Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)
2,768,093,835
1,731,422,755
24
CashFlowsFromInvestmentActivitiesAbstract
Cash Flows from Investment Activities:
25
ConstructionAndAcquisitionOfPlantIncludingLandAbstract
Construction and Acquisition of Plant (including land):
26
GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities
Gross Additions to Utility Plant (less nuclear fuel)
2,258,686,786
2,634,454,072
27
GrossAdditionsToNuclearFuelInvestingActivities
Gross Additions to Nuclear Fuel
28
GrossAdditionsToCommonUtilityPlantInvestingActivities
Gross Additions to Common Utility Plant
29
GrossAdditionsToNonutilityPlantInvestingActivities
Gross Additions to Nonutility Plant
30
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities
(Less) Allowance for Other Funds Used During Construction
46,146,117
33,462,076
31
OtherConstructionAndAcquisitionOfPlantInvestmentActivities
Other (provide details in footnote):
31.1
OtherConstructionAndAcquisitionOfPlantInvestmentActivitiesDescription
Other (provide details in footnote):
34
CashOutflowsForPlant
Cash Outflows for Plant (Total of lines 26 thru 33)
2,212,540,669
2,600,991,996
36
AcquisitionOfOtherNoncurrentAssets
Acquisition of Other Noncurrent Assets (d)
37
ProceedsFromDisposalOfNoncurrentAssets
Proceeds from Disposal of Noncurrent Assets (d)
4,243,166
9,756,179
39
InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Investments in and Advances to Assoc. and Subsidiary Companies
162,136
356,735
40
ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies
Contributions and Advances from Assoc. and Subsidiary Companies
5,392,811
392,811
41
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract
Disposition of Investments in (and Advances to)
42
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies
Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44
PurchaseOfInvestmentSecurities
Purchase of Investment Securities (a)
45
ProceedsFromSalesOfInvestmentSecurities
Proceeds from Sales of Investment Securities (a)
46
LoansMadeOrPurchased
Loans Made or Purchased
47
CollectionsOnLoans
Collections on Loans
49
NetIncreaseDecreaseInReceivablesInvestingActivities
Net (Increase) Decrease in Receivables
50
NetIncreaseDecreaseInInventoryInvestingActivities
Net (Increase) Decrease in Inventory
51
NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities
Net (Increase) Decrease in Allowances Held for Speculation
52
NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities
Net Increase (Decrease) in Payables and Accrued Expenses
53
OtherAdjustmentsToCashFlowsFromInvestmentActivities
Other (provide details in footnote):
53.1
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription
Other (provide details in footnote):
(b)
235,976
(d)
1,665,388
57
CashFlowsProvidedFromUsedInInvestmentActivities
Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)
2,202,830,852
2,592,865,129
59
CashFlowsFromFinancingActivitiesAbstract
Cash Flows from Financing Activities:
60
ProceedsFromIssuanceAbstract
Proceeds from Issuance of:
61
ProceedsFromIssuanceOfLongTermDebtFinancingActivities
Long-Term Debt (b)
800,000,000
975,000,000
62
ProceedsFromIssuanceOfPreferredStockFinancingActivities
Preferred Stock
63
ProceedsFromIssuanceOfCommonStockFinancingActivities
Common Stock
622
211
64
OtherAdjustmentsToCashFlowsFromFinancingActivities
Other (provide details in footnote):
64.1
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription
Other: Contributions from Parent
226,556,660
655,545,330
66
NetIncreaseInShortTermDebt
Net Increase in Short-Term Debt (c)
25,083,697
67
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (provide details in footnote):
67.1
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Other (provide details in footnote):
67.2
DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities
Debt Issuance Costs
13,219,007
13,830,728
70
CashProvidedByOutsideSources
Cash Provided by Outside Sources (Total 61 thru 69)
1,013,338,275
1,641,798,510
72
PaymentsForRetirementAbstract
Payments for Retirement of:
73
PaymentsForRetirementOfLongTermDebtFinancingActivities
Long-term Debt (b)
250,000,000
74
PaymentsForRetirementOfPreferredStockFinancingActivities
Preferred Stock
75
PaymentsForRetirementOfCommonStockFinancingActivities
Common Stock
687
253
76
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities
Other (provide details in footnote):
76.1
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Other (provide details in footnote):
76.2
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities
Bond Issuance Costs
78
NetDecreaseInShortTermDebt
Net Decrease in Short-Term Debt (c)
565,942,547
80
DividendsOnPreferredStock
Dividends on Preferred Stock
81
DividendsOnCommonStock
Dividends on Common Stock
775,643,568
745,361,546
83
CashFlowsProvidedFromUsedInFinancingActivities
Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)
578,248,527
896,436,711
85
NetIncreaseDecreaseInCashAndCashEquivalentsAbstract
Net Increase (Decrease) in Cash and Cash Equivalents
86
NetIncreaseDecreaseInCashAndCashEquivalents
Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)
12,985,544
34,994,337
88
CashAndCashEquivalents
Cash and Cash Equivalents at Beginning of Period
69,633,173
34,638,836
90
CashAndCashEquivalents
Cash and Cash Equivalents at End of Period
56,647,629
69,633,173


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities
Changes in comparative balance sheet for certain accounts
Current and Accrued Assets
$ (12,652,371)
Deferred Debits
(279,730,229)
Amortization of Long-Term Debt Expense
1,704,329 
Counterparty Collateral (Posted) Received, Net
12 
Other Noncurrent Liabilities
10,631,494 
Current and Accrued Liabilities
50,104,133 
Deferred Credits
326,409,908 
Fleet Depreciation
10,049,875 
Restricted Cash 77,696,796 
FERC Audit Adjustment 55,999,262 
Other
30,108 
Total Operating Activities - Other
$ 240,243,317 
(b) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities
Changes in comparative balance sheet for certain accounts
Utility Plant
$ 242,069 
Other Property and Investments
(6,093)

$ 235,976 
(c) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities
Changes in comparative balance sheet for certain accounts
Current and Accrued Assets
$ (34,054,647)
Deferred Debits
(217,977,600)
Amortization of Long-Term Debt Expense
1,581,522 
Counterparty Collateral (Posted) Received, Net
28,250 
Other Noncurrent Liabilities
(20,305,051)
Current and Accrued Liabilities
(157,522,138)
Deferred Credits
216,385,579 
Fleet Depreciation
8,809,624 
Restricted Cash (60,908,057)
Total Operating Activities - Other
$ (263,962,518)
(d) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities
Changes in comparative balance sheet for certain accounts
Utility Plant
$ (1,687,398)
Other Property and Investments
22,010 

$ (1,665,388)
Re-capitalized fleet depreciation for the period ended December 31, 2023, has been reclassified in comparison to the 2023 Form 1 to conform with current year presentation, resulting in a decrease to cash outflows within Line 26 "Gross Additions to Utility Plant (less nuclear fuel)" and an equal and offsetting decrease to cash inflows to Line 53.1 "Other Investing Activities".

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
NOTES TO FINANCIAL STATEMENTS
  1. Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement.
  2. Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock.
  3. For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Commission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof.
  4. Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts.
  5. Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
  6. If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein.
  7. For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
  8. For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
  9. Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.
The notes provided herein were derived from the notes disclosed in the Annual Report of Exelon Corporation (Exelon) on Form 10-K for the fiscal year ended December 31, 2024. The notes presented herein were modified to include information relevant to Commonwealth Edison Company (ComEd). All amounts presented within the footnotes are rounded in millions unless otherwise noted.
1. Significant Accounting Policies
Description of Business
ComEd was organized in the State of Illinois in 1913 as a result of the merger of Cosmopolitan Electric Company into the original corporation named Commonwealth Edison Company, which was incorporated in 1907. ComEd is engaged principally in the purchase and regulated retail sale of electricity and the provision of transmission and distribution services to a diverse base of residential, commercial, industrial and wholesale customers in Northern Illinois, including the City of Chicago. ComEd’s retail service territory has an area of approximately 11,450 square miles and an estimated population of 9.2 million. The service territory includes the City of Chicago, an area of about 225 square miles with an estimated population of 2.6 million. ComEd has approximately 4.1 million customers.
Basis of Presentation
ComEd is a principal indirect subsidiary of Exelon, which owns more than 99% of ComEd’s common stock.
Accounting policies for regulated operations are in accordance with those prescribed by the regulatory authorities having jurisdiction, principally the Illinois Commerce Commission (ICC) under state public utility laws and the Federal Energy Regulatory Commission (FERC). The accompanying financial statements have been prepared in accordance with the accounting requirements of FERC as set forth in the Uniform System of Accounts (USOA) and accounting releases, which differ from accounting principles generally accepted in the United States (GAAP). The principal differences from GAAP include the exclusions of current maturities of long-term debt from current liabilities, the exclusion of debt issuance costs from long-term debt, the exclusion of restricted cash within Cash and cash equivalents in the Statement of Cash Flows, the requirement to report deferred tax assets and liabilities separately rather than as a single amount, the classification of accrued taxes as assets and liabilities rather than a net amount, the exclusion of FIN 48 liabilities related to temporary income tax differences, the derecognition of operating leases from the balance sheet, the classification of cloud computing costs, and the classification of certain other assets and liabilities as current instead of noncurrent.
ComEd’s investments in Commonwealth Edison Company of Indiana, Inc. (ComEd of Indiana), RITELine Illinois, LLC and EdiSun, LLC are accounted for under the equity method of accounting in accordance with the USOA. These entities are consolidated in ComEd’s GAAP financial statements.
ComEd’s investment in ComEd Financing III is accounted for under the equity method of accounting in accordance with the USOA. This entity is not consolidated in ComEd’s GAAP financial statements.
Revision of Previously Issued Financial Statements
Management identified an error in ComEd's previously issued financial statements attributable to the presentation of recapitalized fleet depreciation in the Statement of Cash Flows. As a result of the error, ComEd's Statement of Cash Flows for the year ended December 31, 2023 reflected an overstatement of the cash outflow attributable to Gross additions to utility plant (less nuclear fuel) of $40 million, and an equal and offsetting understatement of the cash outflow attributable to Other investing activities. The error did not impact net cash flows provided by operating activities, net cash flows used in investing activities, or net cash flows provided by financing activities for the year ended December 31, 2023. Furthermore, there was no impact on ComEd's Balance Sheet as of December 31, 2023 or Income Statement for the year ended December 31, 2023.
ComEd management has concluded the error was not material to previously issued financial statements. The Statement of Cash Flows for the year ended December 31, 2023 was revised to reflect the correction of the error.
Use of Estimates
The preparation of financial statements in conformity with USOA requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Areas in which significant estimates have been made include, but are not limited to, the accounting for pension and other postretirement employee benefits (OPEB), unbilled energy revenues, allowance for uncollectible accounts, inventory provision, goodwill, and long-lived asset impairments, derivative instruments, fixed asset depreciation, capitalization of indirect construction costs, environmental costs
and other loss contingencies, asset retirement obligations (AROs), and income taxes. Actual results could differ from those estimates.
Regulatory Accounting
For its regulated electric operations, ComEd reflects the effects of cost-based rate regulation in its financial statements, which is required for entities with regulated operations that meet the following criteria: 1) rates are established or approved by a third-party regulator; (2) rates are designed to recover the entities’ cost of providing services or products; and (3) there is a reasonable expectation that rates designed to recover costs can be charged to and collected from customers. ComEd accounts for its regulated operations in accordance with regulatory and legislative guidance from the regulatory authority having jurisdiction, principally the ICC, under state public utility laws and the FERC under various Federal laws. Regulatory assets and liabilities are amortized and the related expense or revenue is recognized in the Statement of Income consistent with the recovery or refund included in customer rates. ComEd's regulatory assets and liabilities as of the balance sheet date are probable of being recovered or settled in future rates. If a separable portion of ComEd's business was no longer able to meet the criteria discussed above, ComEd would be required to eliminate from its financial statements the effects of regulation for that portion, which could have a material impact on its financial statements. See Note 2—Regulatory Matters for additional information.
ComEd treats the impacts of a final rate order received after the balance sheet date but prior to the issuance of the financial statements as a non-recognized subsequent event, as the receipt of a final rate order is a separate and distinct event that has future impacts on the parties affected by the order.
Revenues
Operating Revenues. ComEd’s operating revenues generally consist of revenues from contracts with customers involving the sale and delivery of power and utility revenues from alternative revenue programs (ARP). ComEd recognizes revenue from contracts with customers to depict the transfer of goods or services to customers in an amount that the entities expect to be entitled to in exchange for those goods or services. ComEd's primary sources of revenue include regulated electric tariff sales, distribution and transmission services. At the end of each month, ComEd accrues an estimate for the unbilled amount of energy delivered or services provided to customers.
ComEd records ARP revenue for its best estimate of the electric distribution, energy efficiency, and transmission revenue impacts resulting from future changes in rates that ComEd believes are probable of approval by the ICC and FERC in accordance with its distribution multi-year rate plan, distribution revenue decoupling mechanisms, and formula rate mechanisms. See Note 2—Regulatory Matters for additional information.
Taxes Directly Imposed on Revenue-Producing Transactions. ComEd collects certain taxes from customers such as sales and gross receipts taxes, along with other taxes, surcharges and fees, that are levied by state or local governments on the sale or distribution of electricity. Some of these taxes are imposed on the customer, but paid by ComEd, while others are imposed on ComEd. Where these taxes are imposed on the customer, such as sales taxes, they are reported on a net basis with no impact to the Statement of Income. However, where these taxes are imposed on ComEd, such as gross receipts taxes or other surcharges or fees, they are reported on a gross basis. Accordingly, revenues are recognized for the taxes collected from customers along with an offsetting expense. See Note 14— Supplemental Financial Information for ComEd’s utility taxes that are presented on a gross basis.
Income Taxes
Deferred federal and state income taxes are recorded on significant temporary differences between the book and tax basis of assets and liabilities and for tax benefits carried forward. Investment tax credits have been deferred in ComEd's Balance Sheets and are recognized in book income over the life of the related property. In accordance with USOA, ComEd reports deferred income tax balances arising from temporary differences in Accounts 190, 282 and 283 as appropriate, which differs from the net presentation required by GAAP. See Note 7—Income Taxes for additional information. ComEd recognizes accrued interest related to unrecognized tax benefits in interest expense or interest income in Net Interest Charges and Other Income, respectively on its Statements of Income.
ComEd accounts for uncertain income tax positions using a benefit recognition model with a two-step approach; a more-likely-than-not recognition criterion; and a measurement approach that measures the position as the largest amount of tax benefit that is greater than 50% likely of being realized upon ultimate settlement. If it is not more-likely-than-not that the benefit of the tax position will be sustained on its technical merits, no benefit is recorded. Uncertain tax positions that relate only to timing of when an item is included on a tax return are considered to have met the recognition threshold.
ComEd accounts for uncertain income tax positions in accordance with FERC's guidance on Accounting and Financial Reporting for Uncertainty in Income Taxes, issued in Docket No. AI07-2-000 for FERC reporting purposes. The guidance
requires, among other things, that entities should continue to recognize deferred income taxes for FERC accounting and reporting purposes based on the difference between positions taken in tax returns filed or expected to be filed and amounts reported in financial statements.
Cash and Cash Equivalents
ComEd considers investments purchased with an original maturity of three months or less to be cash equivalents.
Restricted Cash and Cash Equivalents
Restricted cash and cash equivalents represent funds that are restricted to satisfy designated current liabilities. As of December 31, 2024 and 2023, ComEd’s restricted cash and cash equivalents primarily represented cash collateral held from suppliers associated with ComEd’s energy and renewable energy credits (REC) procurement contracts, any over-recovered Renewable Energy Portfolio Standards (RPS) costs and alternative compliance payments received from Retail Electric Suppliers (RES) pursuant to the Future Energy Jobs Act (FEJA), and costs for the remediation of a Manufactured Gas Plant (MGP) site.
Restricted cash and cash equivalents not available to satisfy current liabilities are classified as noncurrent assets. As of December 31, 2024 and 2023, ComEd's noncurrent restricted cash and cash equivalents primarily represented over-recovered RPS costs and alternative compliance payments received from RES pursuant to FEJA and costs for the remediation of an MGP site.
Accumulated Provision for Uncollectible Accounts on Accounts Receivables
The accumulated provision for uncollectible accounts reflects ComEd's best estimate of losses on the customers' accounts receivable balances based on historical experience, current information, and reasonable and supportable forecasts.
The accumulated provision for uncollectible accounts is estimated based on historical loss experience, current conditions, and forward looking risk factors. ComEd's customer accounts are written off consistent with approved regulatory requirements. Adjustments to the accumulated provision for uncollectible accounts are primarily recorded to Operating and maintenance expense on ComEd's Statement of Income or Regulatory assets and liabilities on ComEd's Balance Sheets. See Note 2 — Regulatory Matters for additional information regarding the regulatory recovery of uncollectible accounts expense on customers' accounts receivable.
ComEd has certain non-customer receivables in Other deferred debits and other assets which primarily are with governmental agencies and other high-quality counterparties with no history of default. As such, the accumulated provision for uncollectible accounts related to these receivables is not material. ComEd monitors these balances and will record an allowance if there are indicators of a decline in credit quality. See Note 3 — Accounts Receivable for additional information.
Inventories
Inventory is recorded at the lower of weighted average cost or net realizable value. Provisions are recorded for excess and obsolete inventory. Materials and supplies are generally included in inventory when purchased. Materials and supplies inventory generally includes transmission and distribution materials and are expensed to Operating and maintenance or capitalized to Property, plant, and equipment, as appropriate, when installed or used.
Property, Plant and Equipment
Property, plant and equipment is recorded at original cost. Original cost includes construction-related direct labor and material costs and indirect construction costs including labor and related costs of departments associated with supporting construction activities. When appropriate, original cost also includes allowance for funds used during construction (AFUDC) for regulated property. The cost of repairs and maintenance and minor replacements of property is charged to Operating and maintenance expense as incurred.
Third parties reimburse ComEd for all or a portion of expenditures for certain capital projects. Such contributions in aid of construction costs (CIAC) are recorded as a reduction to Property, plant and equipment, net.
Upon retirement, the cost of property, net of salvage, is charged to accumulated depreciation consistent with the composite and group methods of depreciation. Depreciation expense includes the estimated cost of dismantling and removing plant from service upon retirement. Actual incurred removal costs are applied against a related regulatory liability or recorded to a regulatory asset if in excess of previously collected removal costs.
Capitalized Software. Certain costs, such as design, coding, and testing incurred during the application development stage of software projects that are internally developed or purchased for operational use are capitalized within Property, plant, and
equipment. Similar costs incurred for cloud-based solutions treated as service arrangements are capitalized within Property, plant, and equipment. Such capitalized amounts are amortized ratably over the expected lives of the projects when they become operational, generally not to exceed five years. Certain other capitalized software costs are being amortized over longer lives, based on the expected life or pursuant to prescribed regulatory requirements.
Allowance for Funds Used During Construction (AFUDC). AFUDC is the cost, during the period of construction, of debt and equity funds used to finance construction projects for regulated operations. AFUDC is recorded to construction work in progress and as a non-cash credit to an allowance that is included in interest expense for debt-related funds and other income and deductions for equity-related funds. The rates used for capitalizing AFUDC are computed under a method prescribed by regulatory authorities.
See Note 4 — Property, Plant, and Equipment for additional information.
Depreciation and Amortization
Depreciation is generally recorded over the estimated service lives of property, plant and equipment on a straight-line basis using the group or composite methods of depreciation. The group approach is typically for groups of similar assets that have approximately the same useful lives and the composite approach is used for dissimilar assets that have different lives. Under both methods, a reporting entity depreciates the assets over the average life of the assets in the group. ComEd's depreciation expense includes the estimated cost of dismantling and removing plant from service upon retirement, which is consistent with ComEd's regulatory recovery method. The estimated service lives for ComEd are based on a combination of depreciation studies and historical retirements. See Note 4Property, Plant, and Equipment for additional information regarding depreciation.
Amortization of regulatory assets and liabilities is recorded over the recovery or refund period specified in the related legislation or regulatory order or agreement. When the recovery or refund period is less than one year, amortization is recorded to the line item in which the deferred cost or income would have originally been recorded in ComEd's Statement of Income. Amortization of ComEd’s electric distribution and energy efficiency formula rate regulatory assets and ComEd’s transmission formula rate regulatory asset is recorded to Operating revenues.
Amortization of income tax related regulatory assets and liabilities is generally recorded to Income tax expense. Except for the regulatory assets and liabilities discussed above, amortization is generally recorded to Depreciation and amortization in ComEd's Statement of Income when the recovery period is more than one year.
See Note 2Regulatory Matters for additional information regarding the amortization of ComEd’s regulatory assets and liabilities.
Asset Retirement Obligations
ComEd estimates and recognizes a liability for its legal obligation to perform asset retirement activities even though the timing and/or methods of settlement may be conditional on future events. ComEd updates its AROs either annually or on a rotational basis at least once every three years, based on a risk profile, unless circumstances warrant more frequent updates. The updates factor in new cost estimates, credit-adjusted, risk-free rates (CARFR) and escalation rates, and the timing of cash flows. AROs are accreted throughout each year to reflect the time value of money for these present value obligations through an increase to regulatory assets. See Note 5 — Asset Retirement Obligations for additional information.
Guarantees
If necessary, ComEd recognizes a liability at the time of issuance of a guarantee for the fair value of the obligations it has undertaken.
The liability is reduced or eliminated as ComEd is released from risk under the guarantee. Depending on the nature of the guarantee, ComEd's release from risk may be recognized only upon the expiration or settlement of the guarantee or by a systematic and rational amortization method over the term of the guarantee. See Note 12—Commitments and Contingencies for additional information.
Asset Impairments
Long-Lived Assets. ComEd evaluates the carrying value of its long-lived assets for recoverability whenever events or changes in circumstances indicate that the carrying value of those assets may not be recoverable. Indicators of impairment may include specific regulatory disallowance, abandonment, or plans to dispose of a long-lived asset significantly before the end of its useful life. When the estimated undiscounted future cash flows attributable to the long-lived asset may not be recoverable, the amount of the impairment loss is determined by measuring the excess of the carrying amount of the long-lived asset over its fair value.
Goodwill. Goodwill represents the excess of the purchase price paid over the estimated fair value of the net assets acquired and liabilities assumed in the acquisition of a business. Goodwill is not amortized but is assessed for impairment at least annually or on an interim basis if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. See Note 6 - Intangible Assets for additional information.
Derivative Financial Instruments
Derivatives are recognized on the balance sheet at their fair value unless they qualify for certain exceptions, including the normal purchases and normal sales (NPNS) exception. For derivatives intended to serve as economic hedges, which are not designated for hedge accounting, changes in fair value each period are recognized in earnings or as a regulatory asset or liability. Amounts recognized in earnings are recorded in Operating revenue, Purchased power, or Interest expense in the Statement of Income based on the activity the transaction is economically hedging. Changes in fair value are also recorded as a regulatory asset or liability when there is an ability to recover or return the associated costs or benefits in accordance with regulatory requirements. Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing cash flows in the Statement of Cash Flows, depending on the nature of each transaction. See Note 2Regulatory Matters and Note 9 - Derivative Financial Instruments for additional information.
Retirement Benefits
ComEd participates in Exelon’s defined benefit pension plans and OPEB plans.
The plan obligations and costs of providing benefits under these plans are measured as of December 31. The measurement involves various factors, assumptions, and accounting elections. The impact of assumption changes or experience different from that assumed on pension and OPEB obligations is recognized over time rather than immediately recognized in the Statement of Income. Gains or losses in excess of the greater of ten percent of the projected benefit obligation or the market-related value of plan assets are amortized over the expected average remaining service period of plan participants. See Note 8— Retirement Benefits for additional information.
New Accounting Pronouncements
New Accounting Standards Issued and Not Yet Adopted as of December 31, 2024
The following new authoritative accounting guidance issued by the FASB has not yet been adopted and reflected by ComEd in their financial statements as of December 31, 2024. Unless otherwise indicated, ComEd is currently assessing the impacts such guidance may have (which could be material) in their Balance Sheet, Statement of Income, Statement of Cash Flows and disclosures, as well as the potential to early adopt where applicable. ComEd has assessed other FASB issuances of new standards which are not listed below given the current expectation that such standards will not significantly impact ComEd's financial reporting.
Improvement to Income Tax Disclosures (Issued December 2023). Provides additional disclosure requirements related to the effective tax rate reconciliation and income taxes paid. Under the revised guidance for the effective tax reconciliations, entities would be required to disclose: (1) eight specific categories in the effective tax rate reconciliation in both percentages and reporting currency amount, (2) additional information for reconciling items over a certain threshold, (3) explanation of individual reconciling items disclosed, and (4) provide a qualitative description of the state and local jurisdictions that contribute to the majority of the state income tax expense. For each annual period presented, the new standard requires disclosure of the year-to-date amount of income taxes paid (net of refunds received) disaggregated by federal, state, and foreign. It also requires additional disaggregated information on income taxes paid (net of refunds received) to an individual jurisdiction equal to or greater than 5% of total income taxes paid (net of refunds received). The standard is effective January 1, 2025, with early adoption permitted.

Disaggregation of Income Statement Expenses (Issued November 2024). Provides additional disclosure requirements related to relevant expense captions of income statement expense line items. The revised guidance requires a new tabular disclosure of disaggregated income statement expenses including a break out of (1) purchases of inventory, (2) employee compensation, (3) depreciation, (4) intangible asset amortization, (5) depreciation, depletion, and amortization recognized as part of oil and gas producing activities included in each relevant expense line item on the income statement. The tabular disaggregation should include certain amounts already required to be disclosed under GAAP elsewhere. Any remaining amounts not separately disaggregated quantitatively should include a qualitative description. Additionally, on an annual basis, the standard requires disclosure of management’s definition of selling expenses and the amount of expense. The standard is effective January 1, 2027, with early adoption permitted. ComEd is currently assessing the impacts of this standard.
2. Regulatory Matters
The following matters below discuss the status of material regulatory and legislative proceedings of ComEd.
Distribution Base Rate Case Proceedings
The following table shows the completed distribution base rate case proceedings in 2024.
Completed Distribution Base Rate Case Proceedings
JurisdictionFiling DateServiceRequested Revenue Requirement IncreaseApproved Revenue Requirement IncreaseApproved ROEApproval DateRate Effective Date
Illinois
January 17, 2023(a)
Electric$1,487 $1,045 8.905%December 19, 2024January 1, 2024
April 26, 2024 (amended on September 11, 2024)(b)
$624 $623 9.89%October 31, 2024January 1, 2025
__________
(a) Reflects a four-year cumulative multi-year rate plan (MRP) for January 1, 2024 to December 31, 2027. The MRP was originally approved by the ICC on December 14, 2023 and was subsequently amended on January 10, 2024, April 18, 2024 and December 19, 2024. The December 19, 2024 order provided a total revenue requirement increase of $1.045 billion inclusive of rate increases of approximately $752 million in 2024, $80 million in 2025, $102 million in 2026, and $111 million in 2027.
(b) On October 31, 2024, the Delivery Reconciliation Amount for 2023 defined in Rider Delivery Service Pricing Reconciliation (Rider DSPR) was approved. Rider DSPR allows for the reconciliation of the revenue requirement in effect in the final years in which formula rates are determined and until such time as new rates are established under ComEd's approved MRP. The 2024 order reconciled the delivery service rates in effect in 2023 with the actual delivery service costs incurred in 2023. The reconciliation revenue requirement provides for a weighted average debt and equity return on distribution rate base of 7.02%, inclusive of an allowed ROE of 9.89%, reflecting the monthly yields on 30-year treasury bonds plus 580 basis points.
Transmission Formula Rates
ComEd’s transmission rate is established based on a FERC-approved formula. ComEd is required to file an annual update to the FERC-approved formula on or before May 15, with the resulting rate effective on June 1 of the same year. The annual update is based on prior year actual costs and current year projected capital additions (initial year revenue requirement). The update also reconciles any differences between the revenue requirement in effect beginning June 1 of the prior year and actual costs incurred for that year (annual reconciliation).
For 2024, the following increases/(decreases) were included in ComEd’s electric transmission formula rate update:
Filing Date(a)
Initial Revenue Requirement Increase
Annual Reconciliation Decrease
Total Revenue Requirement Increase
Allowed Return on Rate Base(b)
Allowed ROE(c)
April 24, 2024$32 $(12)$20 8.14 %11.50 %
__________
(a)All rates are effective June 1, 2024 - May 31, 2025, subject to review by interested parties pursuant to review protocols of ComEd's tariff.
(b)Represents the weighted average debt and equity return on transmission rate bases.
(c)The rate of return on common equity includes a 50-basis-point incentive adder for being a member of a Regional Transmission Organization (RTO).
Other State Regulatory Matters
Illinois Regulatory Matters
Clean and Equitable Jobs Act (CEJA). On September 15, 2021, the Governor of Illinois signed into law CEJA. CEJA includes, among other features, (1) procurement of CMCs from qualifying nuclear-powered generating facilities, (2) a requirement to file a general rate case or a new four-year MRP no later than January 20, 2023 to establish rates effective after ComEd’s existing performance-based distribution formula rate sunsets, (3) requirements that ComEd and the ICC initiate and conduct various regulatory proceedings on subjects including ethics, spending, grid investments, and performance metrics.
ComEd Electric Distribution Rates

ComEd filed, and received approval for, its last performance-based electric distribution formula rate update under Energy Infrastructure Modernization Act (EIMA) in 2022; those rates were in effect throughout 2023.
On February 3, 2022, the ICC approved a tariff that established the process under which ComEd reconciled its 2022 and 2023 rate year revenue requirements with actual costs. Those reconciliation amounts were determined using the same process used for prior reconciliations under the performance-based electric distribution formula rate. Using that process, for the rate
years 2022 and 2023 ComEd will ultimately collect revenues from customers reflecting each year’s actual recoverable costs, year-end rate base, and a weighted average debt and equity return on distribution rate base, with the ROE component based on the annual average of the monthly yields of the 30-year U.S. Treasury bonds plus 580 basis points. In April 2023, ComEd filed its first petition with the ICC to reconcile its 2022 actual costs with the approved revenue requirement that was in effect in 2022; the final order was issued on November 30, 2023, for rates beginning January 2024. On April 26 2024, ComEd filed its petition with the ICC to reconcile its 2023 actual costs with the approved revenue requirement that was in effect in 2023; the final order was issued on October 31, 2024, for rates beginning January 2025.

Beginning in 2024, ComEd started recovering from retail customers, subject to certain exceptions, the costs it incurs to provide electric delivery services either through its electric distribution rate or other recovery mechanisms authorized by CEJA. On January 17, 2023, ComEd filed a petition with the ICC seeking approval of a MRP for 2024-2027. The MRP supports a multi-year grid plan (Grid Plan), also filed on January 17, covering planned investments on the electric distribution system within ComEd’s service area through 2027. Costs incurred during each year of the MRP are subject to ICC review and the plan’s revenue requirement for each year will be reconciled with the actual costs that the ICC determines are prudently and reasonably incurred for that year. The reconciliation is subject to adjustment for certain costs, including a limitation on recovery of costs that are more than 105% of certain costs in the previously approved MRP revenue requirement, absent a modification of the rate plan itself. Thus, for example, the rate adjustments necessary to reconcile 2024 revenues to ComEd’s actual 2024 costs incurred would take effect in January 2026 after the ICC’s review during 2025.

On December 14, 2023, the ICC issued a final order. The ICC rejected ComEd’s Grid Plan as non-compliant with certain requirements of CEJA and required ComEd to file a revised Grid Plan. In the absence of an approved Grid Plan, the ICC set ComEd’s forecast revenue requirements for 2024-2027 based on ComEd's approved year-end 2022 rate base. This resulted in a total cumulative revenue requirement increase of $501 million, a $986 million total revenue reduction from the requested cumulative revenue requirement increase but remains subject to annual reconciliation in accordance with CEJA. The final order approved the process and formulas associated with the MRP reconciliation mechanisms. The ICC's December 2023 order also denied ComEd's ability to earn a return on its pension asset.

On December 22, 2023, ComEd filed an application for rehearing on several findings in the final order including the use of the 2022 year-end rate base to establish forecast revenue requirements for 2024-2027, ROE, pension asset return, and capital structure. On January 10, 2024, ComEd’s application for rehearing was denied on all issues except for the order’s use of the 2022 year-end rate base. On April 18, 2024, the ICC issued its final order on rehearing, which approved the use of the forecasted year-end 2023 rate base that resulted in increased revenue requirements for 2024-2027. These revenue requirements determined during the rehearing process established base revenue requirements until the ICC approved the Refiled Grid Plan on December 19, 2024.

On January 10, 2024, ComEd also filed an appeal in the Illinois Appellate Court of the issues on which rehearing was denied, including but not limited to the allowed ROE, 50% equity ratio, and denial of a return on ComEd’s pension asset. There is no deadline by when the appellate court must rule. On March 13, 2024, ComEd filed its Refiled Grid Plan with supporting testimony and schedules with the ICC and subsequently on March 15, 2024, ComEd also filed a petition to adjust its MRP to authorize increased rates consistent with the Refiled Grid Plan. On December 19, 2024, the ICC approved the Refiled Grid Plan and adjusted the approved MRP with rates effective on January 1, 2025. The final approved MRP, as adjusted, which reflects the Refiled Grid Plan, resulted in a total cumulative revenue requirement increase of $1.045 billion over the 2024-2027 plan years and remains subject to annual reconciliations in accordance with CEJA. ComEd filed timely requests for rehearing and an appeal of this order, again limited to the on which rehearing of the December 2023 order was denied, including the allowed ROE, 50% equity ratio, and denial of a return on ComEd's pension asset.

In January 2022, ComEd filed a request with the ICC proposing performance metrics that would be used in determining ROE incentives and penalties in the event ComEd filed a MRP in January 2023. On September 27, 2022, the ICC issued a final order approving seven performance metrics that provide symmetrical performance adjustments of 32 total basis points to ComEd’s rate of return on common equity based on the extent to which ComEd achieves the annual performance goals. On November 10, 2022, the ICC granted ComEd's application for rehearing, in part. On April 5, 2023, the ICC issued its final order on rehearing for the performance and tracking metrics proceeding, in which the ICC declined to adopt ComEd's proposed modifications to the reliability and peak load reduction performance metrics. Efforts are underway to implement the performance metrics, which took effect on January 1, 2024. ComEd will make its initial filing in 2025 to assess performance achieved under the metrics in 2024, and to determine any ROE adjustment, which would take effect in 2026. In 2024, ComEd has recognized an estimate of the impact of the performance metrics' adjustment.

Carbon Mitigation Credit
CEJA establishes decarbonization requirements for Illinois as well as programs to support the retention and development of emissions-free sources of electricity. ComEd is required to purchase CMCs from participating nuclear-powered generating facilities between June 1, 2022 and May 31, 2027. The price to be paid for each CMC was established through a competitive bidding process that included consumer-protection measures that capped the maximum acceptable bid amount and a formula that reduces CMC prices by an energy price index, the base residual auction capacity price in the ComEd zone of PJM, and the monetized value of any federal tax credit or other subsidy if applicable. The seller has not provided notification to ComEd or the Illinois Power Agency (IPA) that any subsidies or tax credits, such as nuclear production tax credits that became available for electricity generated beginning January 1, 2024, have been monetized and the IPA did not adjust the CMC price paid by ComEd in 2024. The consumer protection measures contained in CEJA will result in net payments to ComEd ratepayers if the energy index, the capacity price and applicable federal tax credits or subsidy exceed the CMC contract price. Beginning with the June 2022 monthly billing period, ComEd began issuing credits and/or charges to its retail customers under its CMC rider, the Rider Carbon-Free Resource Adjustment (Rider CFRA). A regulatory asset is recorded for the difference between ComEd's costs associated with the procurement of CMCs from participating nuclear power generating facilities and revenues received from customers. The balance as of December 31, 2024 is $179 million.

Under CEJA, the costs of procuring CMCs, including carrying costs, are recovered through Rider CFRA. As originally approved by the ICC, Rider CFRA provides for an annual reconciliation and true-up to actual costs incurred or credits received by ComEd to purchase CMCs, with any difference to be credited to or collected from ComEd’s retail customers in subsequent periods. The difference between the net payments to (or receivables from) ComEd ratepayers and the credits received by ComEd to purchase CMCs is recorded to Purchased power expense with an offset to the regulatory asset (or regulatory liability). On December 21, 2022, ComEd filed an amendment to Rider CFRA proposing that it recover costs or provide credits faster than the tariff allows, implement monthly reconciliations, and allow ComEd to adjust Rider CFRA rates based not only on anticipated differences but also past payments or credits, and implement monthly reconciliations beginning with the June 2023 delivery period. The ICC approved the proposal on January 19, 2023. In addition, on March 24, 2023, ComEd submitted revisions to Rider CFRA which clarified the methodology for calculating interest to be included in the annual reconciliation associated with the June 2022 through May 2023 delivery year. The ICC approved the proposal on April 20, 2023. On February 2, 2024, ComEd filed a petition with the ICC to initiate the reconciliation proceeding for the costs incurred in connection with the procurement of CMCs during the delivery year beginning June 1, 2022 and extending through May 31, 2023.

Excess Deferred Income Taxes

The ICC initiated a docket to accelerate and fully credit to customers TCJA unprotected property-related EDIT no later than December 31, 2025. On July 7, 2022, the ICC issued a final order on the schedule for the acceleration of EDIT amortization, adopting the proposal as submitted by several parties, including ComEd, ICC Staff, the Illinois Attorney General's Office, and the Citizens Utility Board. EDIT amortization will be credited to customers through a new rider from January 1, 2023 through December 31, 2025.

Energy Efficiency

CEJA extends ComEd’s current cumulative annual energy efficiency MWh savings goals through 2040, adds expanded electrification measures to those goals, increases low-income commitments and adds a new performance adjustment to the energy efficiency formula rate. ComEd expects its annual spend to increase in 2023 through 2040 to achieve these energy efficiency MWh savings goals, which is deferred as a separate regulatory asset that is recovered through the energy efficiency formula rate over the weighted average useful life, as approved by the ICC, of the related energy efficiency measures.

Energy Efficiency Formula Rate. FEJA allows ComEd to defer energy efficiency costs (except for any voltage optimization costs which are recovered through electric distribution rates) as a separate regulatory asset that is recovered through the energy efficiency formula rate over the weighted average useful life, as approved by the ICC, of the related energy efficiency measures. ComEd earns a return on the energy efficiency regulatory asset at a rate equal to a weighted average cost of capital, which is based on a year-end capital structure and a statutorily-based formula based on long-term treasury debt. The ROE that ComEd earns on its energy efficiency regulatory asset is subject to a maximum downward or upward adjustment of 200 basis points if ComEd’s cumulative persisting annual MWh savings falls short of or exceeds specified percentage benchmarks of its annual incremental savings goal. ComEd is required to file an update to its energy efficiency formula rate on or before June 1st each year, with resulting rates effective in January of the following year. The annual update is based on projected rate year energy efficiency costs, PJM capacity revenues, and the projected year-end regulatory asset balance less any related deferred income taxes (initial year revenue requirement). The update also reconciles any differences between the revenue requirement in effect for the prior year and actual costs incurred from the year (annual reconciliation). The approved energy efficiency formula rate also provides for revenue decoupling provisions.
During 2024, the ICC approved the following total increases in ComEd's requested energy efficiency revenue requirement:
Filing DateRequested Revenue Requirement Increase
Approved Revenue Requirement Increase(a)
Approved ROEApproval DateRate Effective Date
May 30, 2024$58 $58 9.89 %December 5, 2024January 1, 2025
_________
(a)ComEd's 2025 approved revenue requirement above reflects an increase of $66 million for the initial year revenue requirement for 2025 and a decrease of $8 million related to the annual reconciliation for 2023. The revenue requirement for 2025 provides for a weighted average debt and equity return on the energy efficiency regulatory asset and rate base of 7.02% inclusive of an allowed ROE of 9.89%, reflecting the monthly average yields for 30-year treasury bonds plus 580 basis points. The revenue requirement for the 2023 reconciliation year provides for a weighted average debt and equity return on the energy efficiency regulatory asset and rate base of 7.24% inclusive of an allowed ROE of 10.34%, which includes an upward performance adjustment that increased the ROE. The performance adjustment can either increase or decrease the ROE based upon the achievement of energy efficiency savings goals. See table below for ComEd's regulatory assets associated with its energy efficiency formula rate.
Other Federal Regulatory Matters
FERC Audit. ComEd is subject to periodic audits and investigations by FERC. FERC’s Division of Audits and Accounting initiated a nonpublic audit of ComEd in April 2021 evaluating ComEd’s compliance with (1) approved terms, rates and conditions of its federally regulated service; (2) accounting requirements of the Uniform System of Accounts; (3) reporting requirements of the FERC Form 1; and (4) the requirements for record retention. The audit period extended back to January 1, 2017.
On July 27, 2023, FERC issued a final audit report which included, among other things, findings and recommendations related to ComEd's methodology regarding the allocation of certain overhead costs to capitalized construction costs under FERC regulations, including a suggestion that refunds may be due to customers for amounts collected in previous years. On August 28, 2023, ComEd filed a formal notice of the issues it contested within the audit report. On December 14, 2023, FERC appointed a settlement judge for the contested overhead allocation findings and set the matter for a trial-type hearing. That hearing process was held in abeyance while a formal settlement process, which began in February 2024, took place.

On July 30, 2024, ComEd reached an agreement in principle on the contested overhead allocation finding. As a result of the settlement process, ComEd recorded a charge for the probable disallowance of $70 million of certain currently capitalized construction costs to operating expenses, which are not expected to be recovered in future rates. The final settlement is subject to FERC approval. The existing loss estimate is reflected in ComEd's financial statements as of December 31, 2024. ComEd and FERC staff jointly filed the settlement agreement with FERC for approval on February 11, 2025.

Regulatory Assets and Liabilities
Regulatory assets represent incurred costs that have been deferred because of their probable future recovery from customers through regulated rates. Regulatory liabilities represent the excess recovery of costs or accrued credits that have been deferred because it is probable such amounts will be returned to customers through future regulated rates or represent billings in advance of expenditures for approved regulatory programs.
The following tables provide information about the regulatory assets and liabilities of ComEd as of December 31, 2024 and 2023.
Regulatory Assets (Account 182.3):December 31, 2024December 31, 2023
AMI programs - legacy meters$13 $28 
Asset retirement obligations112 104 
Carbon mitigation credit179 673 
COVID-1911 
Deferred income taxes291 284 
Electric distribution formula rate annual reconciliations554 787 
Electric distribution formula rate significant one-time events98 89 
Energy efficiency costs1,890 1,691 
MGP remediation costs275 286 
Multi-year plan reconciliations81 — 
Renewable energy131 134 
Uncollectible accounts expense126 78 
Zero emissions program58 
Other240 174 
Total Regulatory Assets$3,997 $4,397 
Regulatory Liabilities (Account 254):December 31, 2024December 31, 2023
Decommissioning the Regulatory Agreement Units$3,780 $2,954 
Deferred income taxes1,891 2,178 
Electric energy costs12 
Renewable portfolio standards costs1,369 1,102 
Transmission formula rate annual reconciliations— 14 
Other
Total Regulatory Liabilities$7,053 $6,254 
Descriptions of the regulatory assets and liabilities included in the tables above are summarized below, including their recovery and amortization periods.
Line ItemDescriptionEnd Date of Remaining Recovery/Refund PeriodReturn
AMI programs - Legacy MetersRepresents early retirement costs of legacy meters.2028Yes
Asset retirement obligationsRepresents future legally required removal costs associated with existing AROs.Over the life of the related assets.Yes, once the removal activities have been performed.
Carbon mitigation creditRepresents CMC procurement costs and credits as well as reasonable costs ComEd has incurred to implement and comply with the CMC procurement process.2025No
COVID-19Represents incremental credit losses and direct costs related to COVID-19 incurred primarily in 2020. Direct costs consistent primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.2025Yes
Line ItemDescriptionEnd Date of Remaining Recovery/Refund PeriodReturn
Decommissioning the Regulatory Agreement Units
Represents estimated excess funds at the end of decommissioning the Regulatory Agreement Units. See below regarding Decommissioning the Regulatory Agreement Units for additional information.
Not currently being refunded.No
Deferred income taxesRepresents deferred income taxes that are recoverable or refundable through customer rates, primarily associated with accelerated depreciation, the equity component of AFUDC, and the effects of income tax rate changes, including those resulting from the TCJA.Amounts are recoverable over the period in which the related deferred income taxes reverse, which is generally based on the expected life of the underlying assets. For TCJA, generally refunded over the remaining depreciable life of the underlying assets, except in certain jurisdictions where the commissions have approved a shorter refund period for certain assets not subject to IRS normalization rules.No
Line ItemDescriptionEnd Date of Remaining Recovery/Refund PeriodReturn
Electric distribution formula rate annual reconciliations
Represents under/(over)-recoveries related to electric distribution service costs recoverable through ComEd's performance-based formula rate, which was updated annually with rates effective on January 1st.2026Yes
Electric distribution formula rate significant one-time events
Represents deferred distribution service costs related to ComEd's significant one-time events (e.g., storm costs), which are recovered over 5 years from date of the event.2028Yes
Electric energy costsUnder (over) recoveries related to energy related costs recoverable (refundable) under approved rate riders.2025No
Energy efficiency costs
Represents ComEd's costs recovered through the energy efficiency formula rate tariff and the reconciliation of the difference of the revenue requirement in effect for the prior year and the revenue requirement based on actual prior year costs. Deferred energy efficiency costs are recovered over the weighted average useful life of the related energy measure.2036Yes
MGP remediation costs
Represents environmental remediation costs for MGP sites.
Over the expected remediation period. See Note 12 - Commitments and Contingencies for additional information.
No
Multi-year plan reconciliationsRepresents under-recoveries related to electric distribution multi-year plans.2027Yes
Renewable energyRepresents the change in fair value of ComEd‘s 20-year floating-to-fixed long-term renewable energy swap contracts. 2032
No
Renewable portfolio standard costsRepresents an overcollection of funds from both ComEd customers and alternative retail electricity suppliers to be spent on future renewable energy procurements.$1,296 million to be determined in pending ICC annual reconciliation for the Renewable Energy Adjustment rider.

$73 million to be determined based on the Long-Term Renewable Resources Procurement Plan developed by the Illinois Power Agency
No
Line ItemDescriptionEnd Date of Remaining Recovery/Refund PeriodReturn
Transmission formula rate annual reconciliations
Under (over)-recoveries related to transmission service costs recoverable through ComEd’s FERC formula rates, which are updated annually with rates effective each June 1st.
2026Yes
Uncollectible accounts expenseAmounts represent the difference between annual uncollectible accounts loss expense and revenues collected in rates through ICC-approved riders. The difference between uncollectible accounts expense and revenues collected through rider each calendar year is recovered over a twelve-month period beginning in June of the following calendar year. 2025No
Zero emission creditRepresents ZEC procurement costs and any reasonable costs ComEd has incurred to implement and comply with the ZEC procurement process.Over 9 months starting with the September billing period and ending with the following May billing period.No
Decommissioning the Regulatory Agreement Units
The regulatory agreements with the ICC dictates obligations related to the shortfall or excess of Nuclear Decommissioning Trust (NDT) funds necessary for decommissioning the former ComEd units on a unit-by-unit basis. Given no further recovery from customers is permitted and Constellation retains an obligation to ultimately return excess funds to ComEd customers (on a unit-by-unit basis), to the extent excess funds are expected for each unit, decommissioning-related activities prior to separation on February 1, 2022 were offset in the Statement of Income with an offsetting adjustment to regulatory liabilities and noncurrent receivable from Generation (which is reported within Miscellaneous deferred debits on the Balance Sheet). Following the separation, decommissioning-related activities result in an adjustment to other deferred debits and an equal adjustment to the regulatory liabilities at ComEd. However, given the asymmetric settlement provision that does not allow for continued recovery from ComEd customers in the event of a shortfall, recognition of a regulatory asset is not permissible.
Capitalized Ratemaking Amounts Not Recognized
As of December 31, 2024 and 2023, ComEd had $46 million and $32 million, respectively, of authorized amounts capitalized for ratemaking purposes related to earnings on shareholders' investment on its electric distribution rates and formula rates regulatory assets that are not recognized for financial reporting purposes on the Balance Sheets. These amounts will be recognized as revenues in the Statement of Income in the periods they are billable to customers.
3. Accounts Receivable
Accumulated Provision for Uncollectible Accounts
The following tables present the rollforward of Accumulated Provision for Uncollectible Accounts on Customer Accounts Receivable (Account 144).
For the Year Ended December 31, 2024
Balance at December 31, 2023$69 
Plus: Current period provision for uncollectible accounts(a)
78 
Less: Write-offs, net of recoveries(b)
38 
Balance at December 31, 2024$109 
For the Year Ended December 31, 2023
Balance at December 31, 2022$59 
Plus: Current period provision for uncollectible accounts53 
Less: Write-offs, net of recoveries43 
Balance at December 31, 2023$69 
__________
(a)The increase is primarily a result of increased aging of receivables.
(b)Recoveries were not material.

The following tables present the rollforward of Accumulated Provision for Uncollectible Accounts on Other Accounts Receivable (Account 144).
For the Year Ended December 31, 2024
Balance at December 31, 2023$17 
Plus: Current period provision for uncollectible accounts(a)
21 
Less: Write-offs, net of recoveries(b)
Balance at December 31, 2024$34 

For the Year Ended December 31, 2023
Balance at December 31, 2022$17 
Plus: Current period benefit for uncollectible accounts
Less: Write-offs, net of recoveries
Balance at December 31, 2023$17 
__________
(a)The increase is primarily a result of increased aging of receivables.
(b)Recoveries were not material.

Accrued Utility Revenues
ComEd accrued $335 million and $351 million of unbilled customer revenues at December 31, 2024 and 2023, respectively, in Account 173, Accrued Utility Revenues.
Purchase of Customer and Other Accounts Receivable

ComEd is required under legislation and regulations in Illinois to purchase certain receivables from alternative retail electric suppliers that participate in its consolidated billing. The following table presents the total receivables ComEd purchased:

For the Years Ended December 31,
20242023
Total receivables ComEd purchased$964 $942 
4. Property, Plant, and Equipment
The following table presents the average service life for each asset category in number of years as of December 31, 2024:
Asset CategoryAverage Service Life (years)
Electric - transmission and distribution3-80
Other property, plant and equipment29-50
The following table presents the annual depreciation rates for each asset category:
Annual Depreciation Rates December 31, 2024December 31, 2023
Electric-transmission and distribution3.11%3.04%
Allowance for Funds Used During Construction (AFUDC)
The credits to AFUDC debt and equity were $75 million and $72 million for the years ended December 31, 2024 and 2023, respectively.
See Note 1 - Significant Accounting Policies for additional information regarding property, plant and equipment policies. See Note 10 - Debt and Credit Agreements for additional information regarding ComEd's property, plant and equipment subject to mortgage liens.
5. Asset Retirement Obligations
ComEd has AROs primarily associated with the abatement and disposal of equipment and buildings contaminated with asbestos and polychlorinated biphenyls. See Note 1 — Significant Accounting Policies for additional information on ComEd’s accounting policy for AROs.
The following table provides a rollforward of the AROs reflected on ComEd’s Balance Sheets from December 31, 2022 to December 31, 2024:
AROs at December 31, 2022 (Account 230)
$150 
Revisions in estimates of cash flows(3)
Accretion expense(a)
Payments(2)
AROs at December 31, 2023 (Account 230)
$151 
Revisions in estimates of cash flows12 
Accretion expense(a)
Payments(1)
AROs at December 31, 2024 (Account 230)
$169 
__________
(a)The majority of the accretion is recorded as an increase to a regulatory asset (Account 182.3, Other Regulatory Assets) due to the associated regulatory treatment.
6. Intangible Assets
ComEd’s gross amount of goodwill, accumulated impairment losses, and carrying amount of goodwill were $4,608 million, $1,983 million, and $2,625 million, respectively, for both December 31, 2024 and 2023. There were no additions or impairments during the years ended December 31, 2024 and 2023. The gross amount reflects goodwill recorded in 2000 from the PECO/Unicom (predecessor parent company of ComEd).
Goodwill is recorded in Account 114, Electric Plant Acquisition Adjustments and Account 115, Accumulated Provision for Amortization of Electric Plant Acquisition Adjustments, as approved by FERC (Docket No. AC01-38-000). Goodwill is not amortized, but is subject to an assessment for impairment at least annually, or more frequently if events occur or circumstances change that would more likely than not reduce the fair value of the ComEd reporting unit below its carrying amount. A reporting unit is an operating segment or one level below an operating segment (known as a component) and is the level at which goodwill is assessed for impairment. A component of an operating segment is a reporting unit if the component
constitutes a business for which discrete financial information is available and its operating results are regularly reviewed by segment management. ComEd has a single operating segment. There is no level below this operating segment for which operating results are regularly reviewed by segment management. Therefore, ComEd’s operating segment is considered its only reporting unit for goodwill impairment assessment purposes.
Entities assessing goodwill for impairment have the option of first performing a qualitative assessment to determine whether a quantitative assessment is necessary. As part of the qualitative assessments, ComEd evaluates, among other things, management's best estimate of projected operating and capital cash flows for its businesses, outcomes of recent regulatory proceedings, changes in certain market conditions, including the discount rate and regulated utility peer EBITDA multiples, and the passing margin from its last quantitative assessment performed. If an entity bypasses the qualitative assessment, a quantitative, fair value-based assessment is performed, which compares the fair value of the reporting unit to its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its fair value, the entity recognizes an impairment charge, which is limited to the amount of goodwill allocated to the reporting unit.
Application of the goodwill impairment assessment requires management judgment, including the identification of reporting units and determining the fair value of the reporting unit, which management estimates using a weighted combination of a discounted cash flow analysis and a market multiples analysis. Significant assumptions used in these fair value analyses include discount and growth rates, utility sector market performance and transactions, projected operating and capital cash flows for ComEd's business, and the fair value of debt.
2024 and 2023 Goodwill Impairment Assessment. ComEd qualitatively determined that it was more likely than not that the fair value of its reporting unit exceeded the carrying value and, therefore, did not perform quantitative assessments as of November 1, 2024 and 2023. On December 14, 2023, due to the issuance of the ICC's final order rejecting ComEd’s proposed Grid Plan and establishing retail rates for 2024-2027 as further discussed in Note 2 - Regulatory Matters, Exelon’s stock price decreased approximately 10% triggering an interim quantitative assessment for potential goodwill impairment at ComEd. ComEd performed a quantitative assessment as of December 31, 2023, comparing the estimated fair value of ComEd to its carrying value, and determined there was no indication of goodwill impairment
While the annual and interim assessments indicated no impairments, certain assumptions used to estimate reporting unit fair values are highly sensitive to changes. Adverse regulatory actions or changes in significant assumptions could potentially result in future impairment of ComEd's goodwill, which could be material.
7. Income Taxes
Components of Income Tax Expense or Benefit
Income tax expense (benefit) from continuing operations is comprised of the following components:
For the Years Ended December 31,
20242023
Included in operations:
Federal
   Current$74 $136 
   Deferred(76)39 
   Investment tax credit amortization(1)(1)
State
   Current59 (10)
   Deferred57 150 
Total (Accounts 409.1, 409.2, 410.1, 411.1, 411.4)$113 $314 
The effective income tax rate from continuing operations varies from the U.S. Federal statutory rate principally due to the following:
For the Years Ended December 31,
20242023
U.S. Federal statutory rate21.0 %21.0 %
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit7.8 7.8 
Amortization of investment tax credit, including deferred taxes on basis difference(0.1)(0.1)
Plant basis differences(0.7)(0.4)
Production tax credits and other credits (0.8)(0.4)
Excess deferred tax amortization(17.3)(5.4)
Other(0.3)(0.2)
Effective income tax rate9.6 %22.3 %
The tax effects of temporary differences, which give rise to significant portions of the deferred tax assets and liabilities, as of December 31, 2024 and 2023 are presented below:
20242023
Deferred tax liabilities, net:
Plant basis differences$(5,061)$(4,983)
Derivative financial instruments36 37 
Deferred pension and post-retirement obligation(339)(299)
Deferred debt refinancing costs(4)(5)
Regulatory(515)(405)
Corporate alternative minimum tax47 118 
Other, net250 226 
Deferred income tax liabilities, net (Accounts 190, 282 and 283)$(5,586)$(5,311)
Unamortized investment tax credits (Account 255)(6)(7)
Total deferred income tax liabilities, net and unamortized investment tax credits$(5,592)$(5,318)
The following table provides ComEd's carryforwards as of December 31, 2024:
At December 31, 2024
Federal
Minimum tax credit carryforward(a)
$47 
__________
(a)The Corporate Alternative Minimum Tax credit carryfoward has an indefinite carryforward period.
Tabular reconciliation of unrecognized tax benefits
The following table provides a GAAP reconciliation of ComEd’s unrecognized tax benefits as of December 31, 2024 and 2023:
Unrecognized tax benefits at January 1, 2023$16 
Changes to positions that only affect timing(1)
Increases based on tax positions related to 2023
Decreases based on tax positions prior to 2023(8)
Unrecognized tax benefits at December 31, 2023
$
  
Unrecognized tax benefits at January 1, 2024$
Changes to positions that only affect timing— 
Increases based on tax positions related to 2024
Increases based on tax positions prior to 2024
Unrecognized tax benefits at December 31, 2024
$11 

Recognition of unrecognized tax benefits

As of December 31, 2024 and December 31, 2023, ComEd has $11 million and $6 million, respectively, of unrecognized tax benefits that, if recognized, would decrease the effective tax rate.
Reasonably possible the total amount of unrecognized tax benefits could significantly increase or decrease within 12 months after the reporting date
As of December 31, 2024, ComEd has no unrecognized tax benefits that could significantly decrease within the 12 months after the reporting date.
Total amounts of interest and penalties recognized
As of December 31, 2024 and December 31, 2023, ComEd has accrued interest of $2 million and $1 million, respectively, and no penalties related to income tax positions.
Description of tax years that remain subject to examination by major jurisdiction
 Open Years
Federal consolidated income tax returns2010-2023
Illinois unitary corporate income tax returns2012-2023
Other Tax Matters
Corporate Alternative Minimum Tax
On August 16, 2022, the IRA was signed into law and implemented a new corporate alternative minimum tax (CAMT) that imposes a 15% tax on modified GAAP net income. Corporations are entitled to a tax credit (minimum tax credit) to the extent the CAMT liability exceeds the regular tax liability. This amount can be carried forward indefinitely and used in future years when regular tax exceeds the CAMT.

Based on the existing statue, ComEd is subject to and reports CAMT on an independent basis in the Statement of Income and the Balance Sheets. The deferred tax asset related to the minimum tax credit carryforward will be realized to the extent ComEd’s consolidated deferred tax liabilities exceed the minimum tax credit carryforward. ComEd’s deferred tax liabilities are expected to exceed the minimum tax credit carryforward for the foreseeable future and thus no valuation allowance is required. ComEd is continuing to assess the financial statement impacts of the IRA and will update estimates based on future guidance issued by the U.S. Treasury.

On September 12, 2024, the U.S. Treasury issued proposed regulations providing further guidance addressing the implementation of CAMT. The proposed regulations are consistent with Exelon's prior interpretation and therefore there are no financial statement impacts. Exelon will continue to monitor and assess the potential financial statement impacts of final regulations or other guidance when issued.

Long-Term Marginal State Income Tax Rate

Quarterly, Exelon reviews and updates its marginal state income tax rates for changes in state apportionment. ComEd remeasures its existing deferred income tax balances to reflect the changes in marginal rates, which results in either an
increase or decrease to their net deferred income tax liability balances. ComEd records corresponding regulatory liabilities or assets to the extent such amounts are probable of settlement or recovery through customer rates and an adjustment to income tax expense for all other amounts. There were no adjustments to ComEd's deferred income tax liability balance for the years ended December 31, 2024 and 2023.
Allocation of Tax Benefits
ComEd is party to an agreement with Exelon and other subsidiaries of Exelon that provides for the allocation of consolidated tax liabilities and benefits (Tax Sharing Agreement). The Tax Sharing Agreement provides that each party is allocated an amount of tax similar to that which would be owed had the party been separately subject to tax. In addition, any net federal and state benefits attributable to Exelon is reallocated to ComEd and the other Registrants. That allocation is treated as a contribution to the capital of the party receiving the benefit.

ComEd recorded a federal tax benefit allocation from Exelon under the Tax Sharing Agreement as of December 31, 2024 and 2023 of $29 million and $12 million, respectively.
8. Retirement Benefits
Defined Benefit Pension and Other Postretirement Employee Benefits
The listing below shows the pension and OPEB plans in which ComEd employees participated as of December 31, 2024:
Name of Plan(a):
Qualified Pension Plans:
Exelon Corporation Retirement Program
Exelon Corporation Pension Plan for Bargaining Unit Employees
Exelon Pension Plan
Pepco Holdings LLC Retirement Plan

Non-Qualified Pension Plans:
Exelon Corporation Supplemental Pension Benefit Plan and 2000 Excess Benefit Plan
Exelon Corporation Supplemental Management Retirement Plan
OPEB Plans:
PECO Energy Company Retiree Medical Plan
Exelon Corporation Health Care Program
Pepco Holdings LLC Welfare Plan for Retirees
Exelon Corporation Employees' Life Insurance Plan
Exelon Corporation Health Reimbursement Arrangement Plan
BGE Retiree Medical Plan
Exelon Retiree Medical Plan of Constellation Energy Nuclear Group, LLC
Exelon Retiree Dental Plan of Constellation Energy Nuclear Group, LLC
__________
(a)Employees generally remain in their legacy benefit plans when transferring between operating companies.

Cost Allocation to ComEd
ComEd accounts for its participation in Exelon’s pension and OPEB plans by applying multi-employer accounting. Components of pension and OPEB costs and contributions have been, and will continue to be, allocated to ComEd based on both active and retired employee participation in each plan.
The amounts below represent ComEd's allocated portion of the pension and OPEB plan costs, which were included in Operating expenses (Account 401) within ComEd's Statement of Income and Utility Plant (Account 101-106, 114) within ComEd's Balance Sheets for the years ended December 31, 2024 and 2023:
20242023
Pension and OPEB$72 $26 
Contributions
The following table provides ComEd's contributions to the pension and OPEB plans for the years ended December 31, 2024 and 2023:
20242023
Pension benefits$$24 
OPEB18 17 
Management considers various factors when making pension funding decisions, including actuarially determined minimum contribution requirements under the Employee Retirement Income Security Act of 1974, as amended, contributions required to avoid benefit restrictions and at-risk status as defined by the Pension Protection Act of 2006 (the Act), management of the pension obligation and regulatory implications. The Act requires the attainment of certain funding levels to avoid benefit restrictions (such as an inability to pay lump sums or to accrue benefits prospectively), and at-risk status (which triggers higher minimum contribution requirements and participant notification). The projected contributions below reflect a funding strategy to make annual contributions with the objective of achieving 100% funded status on an accumulated benefit obligation basis over time. This funding strategy helps minimize volatility of future period required pension contributions. Unlike the qualified pension plans, Exelon’s non-qualified pension plans are not funded, given that they are not subject to statutory minimum contribution requirements.
While OPEB plans are also not subject to statutory minimum contribution requirements, Exelon does fund certain of its plans. For Exelon's funded OPEB plans, contributions generally equal accounting costs, however, Exelon’s management has historically considered several factors in determining the level of contributions to its OPEB plans, including liabilities management, levels of benefit claims paid, and regulatory implications (amounts deemed prudent to meet regulatory expectations and best assure continued rate recovery). The amounts below include benefit payments related to unfunded plans.
The following table provides ComEd's planned contributions to the qualified pension plans, planned benefit payments to non-qualified pension plans, and planned contributions to OPEB plans in 2025:
Qualified Pension Plans Non-Qualified Pension Plans OPEB
Planned contributions$187 $$21 
Defined Contribution Savings Plan
ComEd participates in a 401(k) defined contribution savings plans that is sponsored by Exelon. The plan is qualified under applicable sections of the Internal Revenue Code and allow employees to contribute a portion of their pre-tax and/or after-tax income in accordance with specified guidelines. ComEd matches a percentage of the employee contributions up to certain limits. The following table presents the employer contributions and employer matching contributions to the savings plan during the years ended December 31, 2024 and 2023:
20242023
Savings plan matching contributions$46 $47 
9. Derivative Financial Instruments
ComEd uses derivative instruments to manage commodity price risk related to ongoing business operations. ComEd does not execute derivatives for speculative or proprietary trading purposes.
Authoritative guidance requires that derivative instruments be recognized as either assets or liabilities at fair value, with changes in fair value of the derivative recognized in earnings immediately. Other accounting treatments are available through special election and designation, provided they meet specific, restrictive criteria both at the time of designation and on an ongoing basis. These alternative permissible accounting treatments include Normal Purchase Normal Sale (NPNS), cash flow hedges, and fair value hedges. At ComEd, derivative economic hedges related to commodities are recorded at fair value and offset by a corresponding regulatory asset or liability. For all NPNS derivative instruments, accounts receivable or accounts payable are recorded when derivatives settle and revenue or expense is recognized in earnings as the underlying physical commodity is sold or consumed.
ComEd’s use of cash collateral is generally unrestricted unless ComEd is downgraded below investment grade.
Commodity Price Risk
ComEd employs established policies and procedures to manage its risk associated with market fluctuations in commodity prices by entering into physical and financial derivative contracts, which are either determined to be non-derivative or classified as economic hedges.
ComEd procures electric supply through a competitive procurement process approved by the ICC. ComEd’s hedging programs are intended to reduce exposure to energy price volatility and have no direct earnings impact as the costs are fully recovered from customers through regulatory-approved recovery mechanisms. The following table provides a summary of ComEd's primary derivative hedging instruments, listed by commodity and accounting treatment.
CommodityAccounting TreatmentHedging Instrument
ElectricityNPNSFixed price contracts based on all requirements in the IPA procurement plans.
Electricity
Changes in fair value of economic hedge recorded to an offsetting regulatory asset or liability(a)
20-year floating-to-fixed energy swap contracts beginning June 2012 based on the renewable energy resource procurement requirements in the Illinois Settlement Legislation of approximately 1.3 million MWhs per year.
__________
(a)See Note 2 - Regulatory Matters for additional information.
The following table provides a summary of the derivative fair value balances recorded by ComEd as of December 31, 2024 and 2023:
December 31, 2024December 31, 2023
Mark-to-market derivative liabilities - current (Account 242)
$(29)$(27)
Mark-to-market derivative liabilities - noncurrent (Account 253)
(103)(106)
Total mark-to-market derivative liabilities$(132)$(133)
Credit Risk
ComEd would be exposed to credit-related losses in the event of non-performance by counterparties on executed derivative instruments. The credit exposure of derivative contracts, before collateral, is represented by the fair value of contracts at the reporting date.
ComEd has contracts to procure electric supply that provide suppliers with a certain amount of unsecured credit. If the exposure on the supply contract exceeds the amount of unsecured credit, the suppliers may be required to post collateral. The net credit exposure is mitigated primarily by the ability to recover procurement costs through customer rates. As of December 31, 2024 and 2023, the amount of cash collateral held from external counterparties was $176 million and $146 million, respectively, which is recorded in Miscellaneous Current and Accrued Liabilities in the Balance Sheets (Account 242). The amount of cash collateral received from external counterparties remained relatively consistent as of December 31, 2024 due to stable energy prices.
ComEd's electric supply procurement contracts do not contain provisions that would require them to post collateral.
10. Debt and Credit Agreements
Short-Term Borrowings
ComEd meets its short-term liquidity requirements primarily through the issuance of commercial paper. ComEd may use its credit facilities for general corporate purposes, including meeting short-term funding requirements and the issuance of letters of credit.
Commercial Paper
The following table reflects ComEd's commercial paper program supported by the revolving credit agreements as of December 31, 2024 and 2023:
Credit Facility Size at December 31,Outstanding Commercial Paper at December 31,Average Interest Rate on Commercial Paper Borrowings at December 31,
2024(a)
2023(a)
2024202320242023
$1,000 $1,000 $36 $202 4.55 %5.53 %
__________
(a)Excludes credit facility agreements arranged at minority and community banks. See below for additional information.
In order to maintain its commercial paper program in the amounts indicated above, ComEd must have credit facilities in place, at least equal to the amount of its commercial paper program. ComEd does not issue commercial paper in an aggregate amount exceeding the then available capacity under its credit facility.
As of December 31, 2024, ComEd had the following aggregate bank commitments, credit facility borrowings, and available capacity under its credit facility:
Available Capacity at December 31, 2024
Facility Type
Aggregate Bank Commitment(a)
Facility DrawsOutstanding Letters of CreditActualTo Support Additional Commercial Paper
Syndicated Revolver $1,000 $— $15 $985 $949 
__________
(a)Excludes credit facility agreements arranged at minority and community banks. See below for additional information.
The following table reflects ComEd's credit facility agreements arranged at minority and community banks as of December 31, 2024 and 2023. These are excluded from the Maximum Program Size and Aggregate Bank Commitment amounts within the two tables above and the facilities may be used to issue letters of credit.
Aggregate Bank CommitmentsOutstanding Letters of Credit
2024(a)
202320242023
$40 $40 $$
__________
(a)These facilities were entered into on October 4, 2024 and expire October 3, 2025.
Revolving Credit Agreements
On August 29, 2024, ComEd amended and restated its syndicated revolving credit facility, extending the maturity date to August 29, 2029. The credit agreements have an aggregate bank commitment of $1 billion and an interest rate of Secured Overnight Financing Rate (SOFR) plus 1.00%.
Borrowings under ComEd’s revolving credit agreements bear interest at a rate based upon either the prime rate or a SOFR-based rate, plus an adder based upon ComEd’s credit rating. ComEd has an adder of 0 basis points and 100 basis points for prime based and SOFR-based borrowings, respectively. If ComEd loses its investment grade rating, the maximum adders for prime rate borrowings and SOFR-based rate borrowings would be 65 basis points and 165 basis points, respectively. The credit agreements also require ComEd to pay a facility fee based upon the aggregate commitments. The fee varies depending upon the credit rating of ComEd. ComEd had no outstanding amounts on the revolving credit facility as of December 31, 2024.
Short-Term Loan Agreements
On May 9, 2023, ComEd entered into a 364-day term loan agreement for $400 million with a variable rate equal to SOFR plus 1.00% and an expiration date of May 7, 2024. On May 1, 2024, ComEd entered into an agreement to extend the loan through the expiration date of June 28, 2024. The original proceeds from the loan were used to repay outstanding commercial paper obligations and for general corporate purposes. The balance of the loan was repaid on May 16, 2024. Refer to the Issuance of Long-Term Debt table below for further information.
Long-Term Debt
The following table presents the outstanding long-term debt at ComEd as of December 31, 2024 and 2023:
December 31,
RatesMaturity Date20242023
Long-term debt
First Mortgage Bonds:
Fixed rates (Account 221)(a)
2.20 - 6.45%2026 - 2054$12,154 $11,603 
Finance Leases (Accounts 227 and 243)
7.49%2053
Total long-term debt$12,161 $11,611 
Unamortized debt discount and premium, net (Account 225 and 226)(31)(28)
Long-term debt$12,130 $11,583 
Long-term debt to financing trusts(b)
Subordinated debentures to ComEd Financing III (Account 223)6.35%2033$206 $206 
__________
(a)Substantially all of ComEd’s assets, other than expressly excepted property, are subject to the lien of its mortgage indenture.
(b)Amount owed to this financing trust is recorded as Long-term debt to financing trust within ComEd's Balance Sheets.
ComEd issued the following long-term debt on May 13, 2024:
TypeInterest
Rate
MaturityAmountUse of Proceeds
First Mortgage Bonds Series 1365.30 %June 1, 2034$400 Repay existing indebtedness, repay outstanding commercial paper obligations, and to fund other general corporate purposes.
First Mortgage Bonds Series 1375.65 %June 1, 2054400 Repay existing indebtedness, repay outstanding commercial paper obligations, and to fund other general corporate purposes.
Long-term debt maturities at ComEd in the periods 2025 through 2029 and thereafter are as follows:
Year
2025$— 
2026500 
2027350 
2028550 
2029— 
Thereafter10,968 
(a)
Total$12,368 
________
(a)Includes $206 million due to ComEd financing trust.

Debt Covenants
As of December 31, 2024, ComEd is in compliance with its debt covenants.
11. Fair Value of Financial Assets and Liabilities
ComEd measures and classifies fair value measurements in accordance with the hierarchy as defined by authoritative guidance. The hierarchy prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:
Level 1 — quoted prices (unadjusted) in active markets for identical assets or liabilities that ComEd has the ability to liquidate as of the reporting date.
Level 2 — inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.
Level 3 — unobservable inputs, such as internally developed pricing models or third-party valuations for the asset or liability due to little or no market activity for the asset or liability.
Fair Value of Financial Liabilities Recorded at Amortized Cost
The following table presents the carrying amounts and fair values of ComEd's short-term liabilities, long-term debt, and trust preferred securities (long-term debt to financing trusts) as of December 31, 2024 and 2023. ComEd has no financial liabilities classified as Level 1 or measured using the NAV practical expedient.
The carrying amounts of ComEd's short-term liabilities as presented on ComEd's Balance Sheets are representative of their fair value (Level 2) because of the short-term nature of these instruments.
December 31, 2024December 31, 2023
Carrying AmountFair ValueCarrying AmountFair Value
Level 1Level 2Level 3TotalLevel 1Level 2Level 3Total
Long-term debt (Accounts 221, 224-227)(a)
$12,130 $— $10,260 $— $10,260 $11,583 $— $10,210 $— $10,210 
Long-term debt to financing trust (Account 223)206 — — 208 208 206 — — 208 208 
_________
(a)Includes unamortized debt discount and premium, net, and finance lease liabilities which are not fair valued. Refer to Note 10 - Debt and Credit Agreements.

ComEd uses the following methods and assumptions to estimate fair value of financial liabilities recorded at carrying cost:
TypeLevelValuation
Long-Term Debt, including amounts due within one year
Taxable Debt Securities2The fair value is determined by a valuation model that is based on a conventional discounted cash flow methodology and utilizes assumptions of current market pricing curves. ComEd obtains credit spreads based on trades of existing ComEd debt securities as well as other issuers in the utility sector with similar credit ratings. The yields are then converted into discount rates of various tenors that are used for discounting the respective cash flows of the same tenor for each bond or note.
Long-Term Debt to Financing Trusts
Long-Term Debt to Financing Trusts3Fair value is based on publicly traded securities issued by the financing trusts. Due to low trading volume of these securities and qualitative factors, such as market conditions, investor demand, and circumstances related to each issue, this debt is classified as Level 3.
Recurring Fair Value Measurements
The following table presents assets and liabilities measured and recorded at fair value on ComEd’s Balance Sheets on a recurring basis and their level within the fair value hierarchy as of December 31, 2024 and 2023. ComEd has no financial assets or liabilities measured using the NAV practical expedient:
At December 31, 2024Level 1Level 2Level 3Total
Assets
Cash equivalents (Accounts 132-134, 136, and 186)(a)
$390 $— $— $390 
Total assets390 — — 390 
Liabilities
Deferred compensation obligation (Accounts 228.3, 242)— (8)— (8)
Commodity derivative liabilities(b) (Accounts 242, 253)
— — (132)(132)
Total liabilities— (8)(132)(140)
Total net assets (liabilities)$390 $(8)$(132)$250 
At December 31, 2023Level 1Level 2Level 3Total
Assets
Cash equivalents (Accounts 132-134, 136, and 186)(a)
$453 $— $— $453 
Total assets453 — — 453 
Liabilities
Deferred compensation obligation (Accounts 228.3, 242)— (8)— (8)
Commodity derivative liabilities(b) (Accounts 242, 253)
— — (133)(133)
Total liabilities— (8)(133)(141)
Total net assets (liabilities)$453 $(8)$(133)$312 
__________
(a)ComEd excludes cash of $17 million and $46 million as of December 31, 2024 and 2023, respectively, and restricted cash of $176 million and $147 million as of December 31, 2024 and 2023, respectively, and includes long-term restricted cash of $41 million and $174 million as of December 31, 2024 and 2023, respectively, which is reported in Other deferred debits in the Balance Sheets.
(b)The Level 3 balance consists of the current and noncurrent liability of $29 million and $103 million, respectively, as of December 31, 2024, and $27 million and $106 million, respectively, as of December 31, 2023 related to floating-to-fixed energy swap contracts with unaffiliated suppliers.
Reconciliation of Level 3 Assets and Liabilities
The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis during the years ended December 31, 2024 and 2023:
Commodity Derivatives
Balance at December 31, 2023$(133)
Total realized / unrealized gains (losses) included in regulatory assets/liabilities(a)
Balance at December 31, 2024 (Accounts 242, 253)$(132)
(b)
Commodity Derivatives
Balance at December 31, 2022$(84)
Total realized / unrealized gains (losses) included in regulatory assets/liabilities(a)
(49)
Balance at December 31, 2023 (Accounts 242, 253)$(133)
__________
(a)Includes $40 million of decreases in fair value and an increase for realized gains due to settlements of $40 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2024. Includes $83 million of decreases in fair value and an increase for realized gains due to settlements of $34 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2023.
(b)The balance consists of a current (Account 242) and noncurrent (Account 253) liability of $29 million and $103 million, respectively, as of December 31, 2024.
Valuation Techniques Used to Determine Fair Value
Cash Equivalents. Investments with original maturities of three months or less when purchased, including mutual and money market funds, are considered cash equivalents. The fair values are based on observable market prices and, therefore, are included in the recurring fair value measurements hierarchy as Level 1.
Deferred Compensation Obligations. ComEd’s deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. ComEd includes such plans in other current and noncurrent liabilities in its Balance Sheets. The value of ComEd’s deferred compensation obligations is based on the market value of the participants’ notional investment accounts. The underlying notional investments are comprised primarily of equities, mutual funds,
commingled funds, and fixed income securities, which are based on directly and indirectly observable market prices. Since the deferred compensation obligations themselves are not exchanged in an active market, they are categorized as Level 2 in the fair value hierarchy.
The value of certain employment agreement obligations (which are included with the Deferred Compensation Obligation in the tables above) are based on a known and certain stream of payments to be made over time and are categorized as Level 2 within the fair value hierarchy.
Commodity Derivatives. On December 17, 2010, ComEd entered into several 20-year floating to fixed energy swap contracts with unaffiliated suppliers for the procurement of long-term renewable energy and associated RECs. Delivery under the contracts began in June 2012. The fair value of these swaps has been designated as a Level 3 valuation due to the long tenure of the positions and the internal modeling assumptions. The modeling assumptions include using forward power prices. See Note 9 — Derivative Financial Instruments for additional information on mark-to-market derivatives. .
The following table discloses the significant unobservable inputs to the forward curve used to value mark-to-market derivatives:
Type of tradeFair Value at December 31, 2024Valuation TechniqueUnobservable Input2024 Range & Arithmetic Average
Commodity derivatives$(132)Discounted Cash Flow
Forward power price(a)
$30.31$59.88$42.08
Type of tradeFair Value at December 31, 2023Valuation TechniqueUnobservable Input2023 Range & Arithmetic Average
Commodity derivatives$(133)Discounted Cash Flow
Forward power price(a)
$30.27$73.71$43.35
__________
(a)An increase to the forward power price would increase the fair value.
12. Commitments and Contingencies
Commercial Commitments
ComEd's commercial commitments at December 31, 2024, representing commitments potentially triggered by future events, were as follows:
Expiration within
Total202520262027202820292030 and beyond
Letters of credit(a)
$18 $16 $$— $— $— $— 
Surety bonds(b)
36 34 — — — — 
Financing trust guarantees(c)
200 — — — — — 200 
Total commercial commitments$254 $50 $$$— $— $200 

__________
(a)ComEd maintains non-debt letters of credit to provide credit support for certain transactions as requested by third parties.
(b)Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. Historically, payments under the guarantees have not been made and the likelihood of payments being required is remote.
(c)Reflects guarantee of ComEd securities held by ComEd Financing III.
Environmental Remediation Matters
General. ComEd’s operations have in the past, and may in the future, require substantial expenditures to comply with environmental laws. Additionally, under federal and state environmental laws, ComEd is generally liable for the costs of remediating environmental contamination of property now or formerly owned by them and of property contaminated by hazardous substances generated by them. ComEd owns or leases a number of real estate parcels, including parcels on which its operations or the operations of others may have resulted in contamination by substances that are considered hazardous under environmental laws. In addition, ComEd is currently involved in a number of proceedings relating to sites where hazardous substances have been deposited and may be subject to additional proceedings in the future. Unless otherwise disclosed, ComEd cannot reasonably estimate whether it will incur significant liabilities for additional investigation and remediation costs at these or additional sites identified by ComEd, environmental agencies or others, or whether such costs
will be recoverable from third parties, including customers. Additional costs could have a material, unfavorable impact on ComEd's financial statements.
Manufactured Gas Plant (MGP) Sites. ComEd has identified sites where former MGP activities have or may have resulted in actual site contamination. For some sites, there are additional potentially responsible parties that may share responsibility for the ultimate remediation of each location.
ComEd has 16 sites currently under some degree of active study and/or remediation. ComEd expects the majority of the remediation at these sites to continue through at least 2031.
The historical nature of the MGP sites, and the fact that many of the sites have been buried and built over, impacts the ability to determine a precise estimate of the ultimate costs prior to initial sampling and determination of the exact scope and method of remedial activity. Management determines its best estimate of remediation costs using all available information at the time of each study, including probabilistic and deterministic modeling, and the remediation standards currently required by the applicable state environmental agency. Prior to completion of any significant clean up, each site remediation plan is approved by the appropriate state environmental agency.
ComEd, pursuant to an ICC order, is currently recovering environmental remediation costs of former MGP facility sites through customer rates.
In 2024, ComEd completed an annual study of its future estimated MGP remediation requirements. The study resulted in an increase of $13 million to the environmental liability and related Regulatory asset. The increase was primarily due to increased costs resulting from inflation and changes in remediation plans.
At December 31, 2024 and 2023, ComEd had accrued the following undiscounted amounts for environmental liabilities in Account 228.4, Accumulated Miscellaneous Operating Provisions, in its Balance Sheets:
December 31, 2024December 31, 2023
Total environmental investigation and remediation liabilities$285 $303 
Portion of total related to MGP investigation and remediation284 302 
Litigation and Regulatory Matters
Fund Transfer Restrictions. Under applicable law, ComEd can pay dividends only from retained, undistributed or current earnings. A significant loss recorded at ComEd may limit the dividends that it can distribute to Exelon.
ComEd has agreed in connection with financings arranged through ComEd Financing III that it will not declare dividends on any shares of its capital stock in the event that: (1) it exercises its right to extend the interest payment periods on the subordinated debt securities issued to ComEd Financing III; (2) it defaults on its guarantee of the payment of distributions on the preferred trust securities of ComEd Financing III; or (3) an event of default occurs under the Indenture under which the subordinated debt securities are issued. No such event has occurred.
Deferred Prosecution Agreement (DPA) and Related Matters. Exelon and ComEd received a grand jury subpoena in the second quarter of 2019 from the United States Attorney's Office for the Northern District of Illinois (USAO) requiring production of information concerning their lobbying activities in the State of Illinois. On October 4, 2019, Exelon and ComEd received a second grand jury subpoena from the USAO requiring production of records of any communications with certain individuals and entities. On October 22, 2019, the SEC notified Exelon and ComEd that it had also opened an investigation into their lobbying activities. On July 17, 2020, ComEd entered into a DPA with the USAO to resolve the USAO investigation, which included a payment to the U.S. Treasury of $200 million, which was paid in November 2020. The three-year term of the DPA ended on July 17, 2023, and on that same date the court granted the USAO’s motion to dismiss the pending charge against ComEd that had been deferred by the DPA.
On September 28, 2023, Exelon and ComEd reached a settlement with the Securities and Exchange Commission (SEC), concluding and resolving in its entirety the SEC investigation, which related to the conduct identified in the DPA that was entered into by ComEd in July 2020 and successfully exited in July 2023. Under the terms of the settlement, Exelon agreed to pay a civil penalty of $46.2 million and Exelon and ComEd agreed to cease and desist from committing or causing any violations and any future violations of specified provisions of the federal securities laws and rules promulgated thereunder. Exelon recorded an expense and paid the full amount of the penalty in 2023, which was reflected in Operating and maintenance expense within Exelon's Consolidated Statements of Operations and Comprehensive Income.
Subsequent to Exelon announcing the receipt of the USAO subpoenas, various lawsuits were filed, and various demand letters were received, related to the subject of the subpoenas, the conduct described in the DPA and the SEC's investigation, including:

Four putative class action lawsuits against ComEd and Exelon were filed in federal court on behalf of ComEd customers in the third quarter of 2020 alleging, among other things, civil violations of federal racketeering laws. The court granted ComEd and Exelon's motion to dismiss these actions in 2021 and that dismissal was affirmed on appeal in 2022. Plaintiffs have no further appeal rights and therefore the dismissal is final.

Three putative class action lawsuits against ComEd and Exelon were filed in Illinois state court in the third quarter of 2020 seeking restitution and compensatory damages on behalf of ComEd customers. The cases were consolidated into a single action in October of 2020. In 2021, the plaintiffs that filed the class action lawsuits in federal court ("federal plaintiffs") refiled their dismissed state law claims in state court. ComEd and Exelon moved to dismiss both lawsuits. The court dismissed the original consolidated state court lawsuit in December 2021 and dismissed the federal plaintiffs' refiled claims in February 2022. Both sets of plaintiffs appealed their dismissals, and the appeals were consolidated in March 2022. On September 8, 2023, the appellate court, affirmed the dismissals. On December 22, 2023, plaintiffs collectively filed a petition for leave to appeal to the Illinois Supreme Court, which ComEd and Exelon responded to on January 12, 2024. On March 27, 2024, the Illinois Supreme Court denied plaintiff's petition for leave to appeal. The dismissal of this action is final.

On November 3, 2022, a plaintiff filed a putative class action complaint in Lake County, Illinois Circuit Court against ComEd and Exelon for unjust enrichment and deceptive business practices in connection with the conduct giving rise to the DPA. Plaintiff seeks an accounting and disgorgement of any benefits ComEd allegedly obtained from said conduct. ComEd and Exelon filed a motion to dismiss the Complaint on February 3, 2023. On June 16, 2023, the court granted ComEd and Exelon's motion to dismiss the action with prejudice. Plaintiff filed its notice of appeal of that dismissal on July 17, 2023. On April 12, 2024, the appellate court issued its decision affirming dismissal of the action. On June 3, 2024, plaintiff filed a petition for leave to appeal the dismissal to the Illinois Supreme Court, which is discretionary appeal. ComEd and Exelon filed its response to that petition on July 19, 2024. On September 25, 2024, the Illinois Supreme Court denied plaintiff's petition for leave to appeal. The dismissal of this action is now final.

A putative class action lawsuit against Exelon and certain officers of Exelon and ComEd was filed in federal court in December 2019 alleging misrepresentations and omissions in Exelon’s SEC filings related to ComEd’s lobbying activities and the related investigations. The complaint was amended on September 16, 2020, to dismiss two of the original defendants and add other defendants, including ComEd. Defendants filed a motion to dismiss in November 2020. The court denied the motion in April 2021. Following mediation, the parties reached a settlement of the lawsuit, under which defendants agreed to pay plaintiffs $173 million. On May 26, 2023, plaintiffs filed a motion for preliminary approval of the settlement, which the court granted on June 9, 2023. The court granted final settlement approval on September 7, 2023. The settlement was fully covered by insurance and has been paid in full.

Several shareholders have sent letters to the Exelon Board of Directors since 2020 demanding, among other things, that the Exelon Board of Directors investigate and address alleged breaches of fiduciary duties and other alleged violations by Exelon and ComEd officers and directors related to the conduct described in the DPA. In the first quarter of 2021, the Exelon Board of Directors appointed a Special Litigation Committee (SLC) consisting of disinterested and independent parties to investigate and address these shareholders' allegations and make recommendations to the Exelon Board of Directors based on the outcome of the SLC's investigation. In July 2021, one of the demand letter shareholders filed a derivative action against current and former Exelon and ComEd officers and directors, and against Exelon, as nominal defendant, asserting the same claims made in its demand letter. Since that date, multiple parties have filed separate derivative lawsuits that were subsequently consolidated. On October 12, 2021, the parties filed an agreed motion to stay the litigation for 120 days in order to allow the SLC to continue its investigation, which the court granted. The stay was extended several times. Through mediation efforts, a settlement of the derivative claims was reached by the SLC, the Independent Review Committee of the Board (which had been formed in the third quarter of 2022, to ensure the Board’s consideration of any SLC recommendations would be independent and objective), the Board, and certain of the derivative shareholders. On June 16, 2023, the SLC filed a motion for preliminary approval of the settlement, attaching the Stipulation and Agreement of Settlement (Stipulation), which contained the terms of the proposed settlement. The proposed settlement terms include but are not limited to: a payment of $40 million to Exelon by Exelon’s insurers of which $10 million constitutes the attorneys’ fee award to be paid to the Settling Shareholders’ counsel; various compliance and disclosure-related reforms; and certain changes in Board and Committee composition. On June 30, 2023, the court granted the non-settling shareholders’ request for limited discovery into the settlement. Following that discovery, on October 26, 2023, the SLC filed its renewed motion for preliminary approval with supporting submissions filed by the Independent Review Committee, Exelon, and the Settling Shareholders on that same day. The parties briefing on preliminary approval was completed on January 18,
2024. On September 20, 2024, the court denied without prejudice the SLC’s motion for preliminary approval. The court’s order provides that if the SLC can substantiate or otherwise revise the attorneys’ fees aspect of the settlement, then the SLC can renew its motion for preliminary approval by October 21, 2024. Otherwise, the court directed the parties to file a joint status report by October 30, 2024, proposing next steps to advance the case. On October 21, 2024, the SLC filed its second renewed motion for preliminary approval, and the Settling Shareholders filed a brief in support of the SLC's second renewed motion for preliminary approval. On November 20, 2024, the non-settling plaintiffs filed an opposition to the renewed motion for preliminary approval. On December 18, 2024, the SLC and Settling Shareholders filed replies in support of the renewed motion for preliminary approval.

In August 2022, the ICC concluded its investigation initiated on August 12, 2021 into rate impacts of conduct admitted in the DPA, including the costs recovered from customers related to the DPA and Exelon's funding of the fine paid by ComEd. On August 17, 2022, the ICC issued its final order accepting ComEd's voluntary customer refund offer of approximately $38 million (of which about $31 million was ICC jurisdictional; the remaining balance was FERC jurisdictional) that resolved the question of whether customer funds were used for DPA related activities. The customer refund included the cost of every individual or entity that was either (i) identified in the DPA or (ii) identified by ComEd as an associate of the former Speaker of the Illinois House of Representatives in the ICC proceeding. The ICC’s DPA investigation is now closed. The ICC jurisdictional refund was made to customers during the April 2023 billing cycle, as required by the ICC. The FERC jurisdictional refund was completed as of May 2024 as part of ComEd's transmission formula rate updated proceeding, submitted on May 12, 2023. The customer refund was not recovered in rates or charged to customers and ComEd will not seek or accept reimbursement or indemnification from any source other than Exelon.
General. ComEd is involved in various other litigation matters that are being defended and handled in the ordinary course of business. ComEd is also from time to time subject to audits and investigations by the FERC and other regulators. The assessment of whether a loss is probable or reasonably possible, and whether the loss or a range of loss is estimable, often involves a series of complex judgments about future events. ComEd maintains accruals for such losses that are probable of being incurred and subject to reasonable estimation. Management is sometimes unable to estimate an amount or range of reasonably possible loss, particularly where (1) the damages sought are indeterminate, (2) the proceedings are in the early stages, or (3) the matters involve novel or unsettled legal theories. In such cases, there is considerable uncertainty regarding the timing or ultimate resolution of such matters, including a possible eventual loss.
13. Shareholders' Equity
Common Stock Warrants (Account 201)
The following table presents warrants outstanding to purchase ComEd common stock and shares of common stock reserved for the conversion of warrants. The warrants entitle the holders to convert such warrants into common stock of ComEd at a conversion rate of one share of common stock for three warrants.
December 31,
20242023
Warrants outstanding59,970 60,032 
Common stock reserved for conversion19,990 20,011 
Preferred and Preference Securities (Account 204)
The following table presents ComEd's shares of preferred securities authorized, none of which were outstanding, as of December 31, 2024 and 2023:
Preferred Securities Authorized
ComEd's shares850,000 
The following table presents ComEd's preference securities authorized, none of which were outstanding as of December 31, 2024 and 2023:
Preference Securities Authorized
ComEd6,810,451 
14. Supplemental Financial Information
Supplemental Statement of Income Information
The following table provides additional information about material items recorded in ComEd's Statement of Income:
For the Years Ended December 31,
20242023
Taxes other than income (Accounts 408.1 and 408.2)
Utility(a)
$300 $299 
Property32 33 
Payroll37 31 
________
(a)ComEd’s utility taxes represent municipal and state utility taxes and gross receipts taxes related to its operating revenues. The offsetting collection of utility taxes from customers is recorded in revenues in ComEd's Statement of Income.
Supplemental Statement of Cash Flows Information
The following tables provide additional information about material items recorded in ComEd's Statement of Cash Flows:
For the Years Ended December 31,
20242023
Cash paid during the year
Interest (net of amount capitalized)
$485 $441 
Income taxes (net of refunds)250 11 
Non-cash investing activities
Decrease in capital expenditures not paid$(17)$(10)
15. Related Party Transactions
Service Company Costs for Corporate Support
ComEd receives a variety of corporate support services from Exelon's Business Services Corporation (BSC). The following table presents the service company costs allocated to ComEd:
Operating and maintenance from affiliateCapitalized costs
For the Years Ended December 31,For the Years Ended December 31,
2024202320242023
BSC$418 $353 $254 $307 

Current Payables to affiliates
The following table presents ComEd's current payables to affiliates:
At December 31,
20242023
BSC$67 $64 
ComEd Financing III
ComEd of Indiana
Other
Total (Account 234)$77 $73 
Noncurrent Receivables from affiliates
The following table presents ComEd's noncurrent receivables from affiliates:
At December 31,
20242023
Other
$$
Total (Account 186)$$
Long-term debt to financing trusts
The following table presents ComEd's Long-term debt to financing trusts:
At December 31,
20242023
ComEd Financing III$206 $205 


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
  1. Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate.
  2. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges.
  3. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote.
  4. Report data on a year-to-date basis.
Line No.
Item
(a)
Unrealized Gains and Losses on Available-For-Sale Securities
(b)
Minimum Pension Liability Adjustment (net amount)
(c)
Foreign Currency Hedges
(d)
Other Adjustments
(e)
Other Cash Flow Hedges Interest Rate Swaps
(f)
Other Cash Flow Hedges [Specify]
(g)
Totals for each category of items recorded in Account 219
(h)
Net Income (Carried Forward from Page 116, Line 78)
(i)
Total Comprehensive Income
(j)
1
Balance of Account 219 at Beginning of Preceding Year
2
Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3
Preceding Quarter/Year to Date Changes in Fair Value
4
Total (lines 2 and 3)
1,094,078,343
1,094,078,343
5
Balance of Account 219 at End of Preceding Quarter/Year
6
Balance of Account 219 at Beginning of Current Year
7
Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8
Current Quarter/Year to Date Changes in Fair Value
9
Total (lines 7 and 8)
1,066,087,097
1,066,087,097
10
Balance of Account 219 at End of Current Quarter/Year


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION

Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.

Line No.
Classification
(a)
Total Company For the Current Year/Quarter Ended
(b)
Electric
(c)
Gas
(d)
Other (Specify)
(e)
Other (Specify)
(f)
Other (Specify)
(g)
Common
(h)
1
UtilityPlantAbstract
UTILITY PLANT
2
UtilityPlantInServiceAbstract
In Service
3
UtilityPlantInServiceClassified
Plant in Service (Classified)
38,020,748,357
38,020,748,357
4
UtilityPlantInServicePropertyUnderCapitalLeases
Property Under Capital Leases
7,849,772
7,849,772
5
UtilityPlantInServicePlantPurchasedOrSold
Plant Purchased or Sold
6
UtilityPlantInServiceCompletedConstructionNotClassified
Completed Construction not Classified
1,064,604,469
1,064,604,469
7
UtilityPlantInServiceExperimentalPlantUnclassified
Experimental Plant Unclassified
8
UtilityPlantInServiceClassifiedAndUnclassified
Total (3 thru 7)
39,093,202,598
39,093,202,598
9
UtilityPlantLeasedToOthers
Leased to Others
10
UtilityPlantHeldForFutureUse
Held for Future Use
99,953,769
99,953,769
11
ConstructionWorkInProgress
Construction Work in Progress
1,220,404,574
1,220,404,574
12
UtilityPlantAcquisitionAdjustment
Acquisition Adjustments
2,774,314,255
2,774,314,255
13
UtilityPlantAndConstructionWorkInProgress
Total Utility Plant (8 thru 12)
43,187,875,196
43,187,875,196
14
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Accumulated Provisions for Depreciation, Amortization, & Depletion
12,206,668,092
12,206,668,092
15
UtilityPlantNet
Net Utility Plant (13 less 14)
30,981,207,104
30,981,207,104
16
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract
In Service:
18
DepreciationUtilityPlantInService
Depreciation
11,280,254,100
11,280,254,100
19
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService
Amortization and Depletion of Producing Natural Gas Land and Land Rights
20
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService
Amortization of Underground Storage Land and Land Rights
21
AmortizationOfOtherUtilityPlantUtilityPlantInService
Amortization of Other Utility Plant
777,039,377
777,039,377
22
DepreciationAmortizationAndDepletionUtilityPlantInService
Total in Service (18 thru 21)
12,057,293,477
12,057,293,477
23
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract
Leased to Others
24
DepreciationUtilityPlantLeasedToOthers
Depreciation
25
AmortizationAndDepletionUtilityPlantLeasedToOthers
Amortization and Depletion
26
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers
Total Leased to Others (24 & 25)
27
DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract
Held for Future Use
28
DepreciationUtilityPlantHeldForFutureUse
Depreciation
29
AmortizationUtilityPlantHeldForFutureUse
Amortization
30
DepreciationAndAmortizationUtilityPlantHeldForFutureUse
Total Held for Future Use (28 & 29)
31
AbandonmentOfLeases
Abandonment of Leases (Natural Gas)
32
AmortizationOfPlantAcquisitionAdjustment
Amortization of Plant Acquisition Adjustment
149,374,615
149,374,615
33
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility
Total Accum Prov (equals 14) (22,26,30,31,32)
12,206,668,092
12,206,668,092


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
  1. Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent.
  2. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.
Description of item
(a)
Balance Beginning of Year
(b)
Changes during Year Additions
(c)
Changes during Year Amortization
(d)
Changes during Year Other Reductions (Explain in a footnote)
(e)
Balance End of Year
(f)
1
Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2
Fabrication
3
Nuclear Materials
4
Allowance for Funds Used during Construction
5
(Other Overhead Construction Costs, provide details in footnote)
6
SUBTOTAL (Total 2 thru 5)
7
Nuclear Fuel Materials and Assemblies
8
In Stock (120.2)
9
In Reactor (120.3)
10
SUBTOTAL (Total 8 & 9)
11
Spent Nuclear Fuel (120.4)
12
Nuclear Fuel Under Capital Leases (120.6)
13
(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)
14
TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)
15
Estimated Net Salvage Value of Nuclear Materials in Line 9
16
Estimated Net Salvage Value of Nuclear Materials in Line 11
17
Est Net Salvage Value of Nuclear Materials in Chemical Processing
18
Nuclear Materials held for Sale (157)
19
Uranium
20
Plutonium
21
Other (Provide details in footnote)
22
TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
  1. Report below the original cost of electric plant in service according to the prescribed accounts.
  2. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric.
  3. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year.
  4. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments.
  5. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts.
  6. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year.
  7. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications.
  8. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages.
  9. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.
Account
(a)
Balance Beginning of Year
(b)
Additions
(c)
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at End of Year
(g)
1
1. INTANGIBLE PLANT
2
(301) Organization
80,375
80,375
3
(302) Franchise and Consents
4
(303) Miscellaneous Intangible Plant
1,172,518,522
412,477,542
247,998,085
1,336,997,979
5
TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)
1,172,598,897
412,477,542
247,998,085
1,337,078,354
6
2. PRODUCTION PLANT
7
A. Steam Production Plant
8
(310) Land and Land Rights
9
(311) Structures and Improvements
10
(312) Boiler Plant Equipment
11
(313) Engines and Engine-Driven Generators
12
(314) Turbogenerator Units
13
(315) Accessory Electric Equipment
14
(316) Misc. Power Plant Equipment
15
(317) Asset Retirement Costs for Steam Production
16
TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)
17
B. Nuclear Production Plant
18
(320) Land and Land Rights
19
(321) Structures and Improvements
20
(322) Reactor Plant Equipment
21
(323) Turbogenerator Units
22
(324) Accessory Electric Equipment
23
(325) Misc. Power Plant Equipment
24
(326) Asset Retirement Costs for Nuclear Production
25
TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
26
C. Hydraulic Production Plant
27
(330) Land and Land Rights
28
(331) Structures and Improvements
29
(332) Reservoirs, Dams, and Waterways
30
(333) Water Wheels, Turbines, and Generators
31
(334) Accessory Electric Equipment
32
(335) Misc. Power Plant Equipment
33
(336) Roads, Railroads, and Bridges
34
(337) Asset Retirement Costs for Hydraulic Production
35
TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
36
D. Other Production Plant
37
(340) Land and Land Rights
38
(341) Structures and Improvements
39
(342) Fuel Holders, Products, and Accessories
40
(343) Prime Movers
41
(344) Generators
42
(345) Accessory Electric Equipment
43
(346) Misc. Power Plant Equipment
44
(347) Asset Retirement Costs for Other Production
44.1
(348) Energy Storage Equipment - Production
45
TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)
46
TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)
47
3. Transmission Plant
48
(350) Land and Land Rights
189,527,542
189,527,542
48.1
(351) Energy Storage Equipment - Transmission
49
(352) Structures and Improvements
789,306,978
77,781,835
1,025,897
2,189,021
863,873,895
50
(353) Station Equipment
3,142,002,375
42,328,139
6,025,721
7,215,496
3,171,089,297
51
(354) Towers and Fixtures
272,198,248
4,258,768
255,762
267,683,718
52
(355) Poles and Fixtures
981,356,114
67,161,452
12,254
2,267,254
1,046,238,058
53
(356) Overhead Conductors and Devices
704,151,980
5,747,338
394,492
1,409,700
708,095,126
54
(357) Underground Conduit
231,905,697
3,042,582
33,188
413,733
234,501,358
55
(358) Underground Conductors and Devices
563,494,421
13,228,185
240,527
1,232,171
575,249,908
56
(359) Roads and Trails
20,721,058
4,652,422
61,685
25,311,795
57
(359.1) Asset Retirement Costs for Transmission Plant
7,580,060
108,770
2,400,422
9,871,712
58
TOTAL Transmission Plant (Enter Total of lines 48 thru 57)
6,902,244,473
209,683,185
7,840,849
12,644,400
7,091,442,409
59
4. Distribution Plant
60
(360) Land and Land Rights
76,051,352
2,884
185,458
76,233,926
61
(361) Structures and Improvements
906,673,194
65,532,652
678,191
362,704
971,164,951
62
(362) Station Equipment
4,066,720,575
233,833,367
12,937,384
2,896,138
4,284,720,420
63
(363) Energy Storage Equipment – Distribution
274,704
274,704
64
(364) Poles, Towers, and Fixtures
3,027,620,827
195,192,010
19,305,842
8,314,719
4,390
3,195,196,666
65
(365) Overhead Conductors and Devices
4,528,132,363
263,176,119
65,705,042
13,084,828
189,354
4,712,329,258
66
(366) Underground Conduit
1,136,372,636
59,583,107
2,649,744
2,324,604
3,005
1,190,984,400
67
(367) Underground Conductors and Devices
8,199,109,515
404,888,781
36,430,435
23,509,826
14,718
8,544,043,317
68
(368) Line Transformers
1,629,783,265
144,333,121
43,176,526
373,428
6,130
1,730,560,302
69
(369) Services
1,475,194,205
31,602,884
4,879,193
3,572,087
1,498,345,809
70
(370) Meters
858,073,532
14,990,380
5,946,561
202,807
867,320,158
71
(371) Installations on Customer Premises
89,805,426
1,577,864
72,995
269,280
91,041,015
72
(372) Leased Property on Customer Premises
824,003
64,293
759,710
73
(373) Street Lighting and Signal Systems
210,198,209
12,981,986
3,388,898
620,994
219,170,303
74
(374) Asset Retirement Costs for Distribution Plant
33,911,783
45,699
9,613,300
43,479,384
75
TOTAL Distribution Plant (Enter Total of lines 60 thru 74)
26,238,745,589
1,427,625,094
195,216,510
45,715,308
185,458
27,425,624,323
76
5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77
(380) Land and Land Rights
78
(381) Structures and Improvements
79
(382) Computer Hardware
80
(383) Computer Software
81
(384) Communication Equipment
82
(385) Miscellaneous Regional Transmission and Market Operation Plant
83
(386) Asset Retirement Costs for Regional Transmission and Market Oper
84
TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85
6. General Plant
86
(389) Land and Land Rights
38,257,667
38,257,667
87
(390) Structures and Improvements
816,198,036
16,401,965
5,322,355
827,277,646
88
(391) Office Furniture and Equipment
168,562,231
28,839,258
27,843,194
169,558,295
89
(392) Transportation Equipment
481,967,231
54,846,808
17,587,396
519,226,643
90
(393) Stores Equipment
8,264,150
8,264,150
91
(394) Tools, Shop and Garage Equipment
282,784,901
15,617,328
33,551,547
264,850,682
92
(395) Laboratory Equipment
17,528,058
3,398,256
123,835
20,802,479
93
(396) Power Operated Equipment
7,740,974
7,740,974
94
(397) Communication Equipment
1,271,557,585
91,609,446
31,984,213
(c)
1,331,182,818
95
(398) Miscellaneous Equipment
23,708,471
8,732,903
1,369,867
31,071,507
96
SUBTOTAL (Enter Total of lines 86 thru 95)
3,116,569,304
219,445,964
117,782,407
3,218,232,861
97
(399) Other Tangible Property
98
(399.1) Asset Retirement Costs for General Plant
13,338,192
363,313
12,974,879
99
TOTAL General Plant (Enter Total of lines 96, 97, and 98)
3,129,907,496
219,445,964
118,145,720
3,231,207,740
100
TOTAL (Accounts 101 and 106)
37,443,496,455
2,269,231,785
569,201,164
58,359,708
185,458
39,085,352,826
101
(102) Electric Plant Purchased (See Instr. 8)
102
(Less) (102) Electric Plant Sold (See Instr. 8)
103
(103) Experimental Plant Unclassified
104
TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)
37,443,496,455
2,269,231,785
569,201,164
(a)
58,359,708
(b)
185,458
39,085,352,826


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: ElectricPlantInServiceAdjustments
The plant in-service adjustments of $12,013,721 is the result of periodic reviews of, and changes to, the Company's asset retirement obligations, intercompany transfers for ($373,429) and an adjustment to FERC account 101 for ($70,000,000) which represents a reduction in plant balance per the February 11, 2025 Settlement Agreement between ComEd and the FERC Office of Enforcement to resolve the labor and labor-related overheads accounting matter in Docket Nos. FA 21-5-000 and FA 21-5-001. Of the ($70,000,000) adjustment, ($54,955,180) was recorded to Distribution and ($15,044,820) was recorded to Transmission.
(b) Concept: ElectricPlantInServiceTransfers
Represents net transfers from Account 105 (Plant Held for Future Use) of $185,458.
(c) Concept: CommunicationEquipment
Of the balance reported in Account 397 (Communication Equipment) of $1,331,182,818 - 30.18% of such amount is directly assignable to the Transmission function and 69.82% of such amount is directly assignable to the Distribution function.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.
LesseeName
Name of Lessee
(a)
IndicationOfAssociatedCompany
* (Designation of Associated Company)
(b)
LeaseDescription
Description of Property Leased
(c)
CommissionAuthorization
Commission Authorization
(d)
ExpirationDateOfLease
Expiration Date of Lease
(e)
ElectricPlantLeasedToOthers
Balance at End of Year
(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
TOTAL


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
  1. Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use.
  2. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.
ElectricPlantHeldForFutureUseDescription
Description and Location of Property
(a)
ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate
Date Originally Included in This Account
(b)
ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
Date Expected to be used in Utility Service
(c)
ElectricPlantHeldForFutureUse
Balance at End of Year
(d)
1 Land and Rights:
2
Transmission Plant (Land and/or Rights):
3
Charter Grove TSS
12/31/2006
(a)
01/01/2030
637,355
4
Cherry Valley-Silver Lake
06/30/1973
01/01/2035
1,827,050
5
Chicago-Northwestern R. R.
12/31/2001
01/01/2035
1,567,260
6
Eakin Creek TSS
09/30/1996
01/01/2035
2,670,479
7
Goodings Grove-Indiana Widening/Crete TSS
09/30/1971
01/01/2033
1,206,117
8
Manville-Pontiac
11/30/1972
01/01/2035
528,398
9
Plano-Charter Grove
06/30/1975
01/01/2030
4,343,302
10
Plato Center - 1
01/31/1992
01/01/2035
426,467
11
Sugar Grove-Blackberry
03/31/1991
01/01/2035
408,473
12
Waukegan Station 354kv Switchyard
12/31/2006
01/01/2035
799,826
13
Wayne-Itasca
12/31/1970
01/01/2035
4,099,384
14
Wilton Center-Joliet
05/31/1973
01/01/2035
352,474
15
Sugar Grove TSS
12/31/2012
01/01/2035
720,587
16
Sawyer TSS
12/31/2019
01/01/2030
441,267
17
Midway Court TSS
04/30/2024
01/01/2028
10,486,744
18
18 items less than $250,000 each
1,303,236
19
20
21
22
23
24
25
26
27
28
21 Other Property:
22
Distribution Plant (Land and/or Rights):
23
Plato Center - 2
01/31/1992
01/01/2037
617,255
24
Rutland TDC
09/30/1996
01/01/2037
372,830
25
Lakeview - 1141 W. Diversey
12/01/2020
01/01/2029
11,729,191
26
Land - Aurora to Elgin-Kane
11/01/2021
01/01/2030
41,557,075
27
Plymouth Court
07/31/2022
01/01/2033
4,715,679
28
Jefferson GIS
12/31/2021
01/01/2028
7,718,755
29
31 items less than $250,000
1,416,284
30
General Plant (Land and\or RIghts)
31
1 items less than $250,000
8,281
47 TOTAL
99,953,769


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate
The expected dates to be used in utility service are estimates and are subject to change.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
  1. Report below descriptions and balances at end of year of projects in process of construction (107).
  2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts).
  3. Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.
ConstructionWorkInProgressProjectDescription
Description of Project
(a)
ConstructionWorkInProgress
Construction work in progress - Electric (Account 107)
(b)
1
Intangible Plant
2
Major projects:
3
EU GIS CORE SW
45,799,781
4
Apollo Phase 2 W/O WPT SW
35,595,710
5
ADMS - Cap Software #2 SW
25,963,092
6
EMS Upgrade - SW
6,302,808
7
Apollo Boundary Apps SW
5,184,733
8
oneMDS Mobile Dispatch - SW
4,644,794
9
PowerPlan Upgrade SW
3,680,940
10
EU GIS DQ SW
3,388,799
11
oneMDS Mobile Dispatch SW RL4
2,660,607
12
ADMS - SW
1,763,429
13
ComEd DERMS 2 SW
1,640,426
14
Predictive Grid Platform
1,531,823
15
EU Reliability and Auto SW
1,477,593
16
LCS-MEU SW
1,415,026
17
GIS Transmission SW
1,386,713
18
ComED VO Refresh SW
1,352,820
19
GDVA Implementation SW
1,271,878
20
Apollo Boundary Apps Cl
1,159,710
21
Other Projects
(a)
7,579,720
22
Transmission Plant
23
TSS 135 Elmhurst 345kV GIS
62,634,572
24
TSS 51 McCook 138kV Line
36,246,099
25
Upgrade 138kV Line 0108
34,506,929
26
TSS 116 Goodings Grove - Insta
20,466,737
27
UA HQ Data Center TSS184
13,742,945
28
Upgrade 345kV L97008
9,042,548
29
INSTALL 3RD TR (40MVA) AT TDC2
8,623,729
30
TSS46 Des Plaines TR83 Rpl
7,398,914
31
TSS184 345kV GIS and Cntrl Eqp
7,303,657
32
Prime Data Center
6,197,130
33
Rebuild L15518-TSS132 & TSS133
4,849,257
34
TSS 101 Itasca - Install 345-1
4,597,619
35
TSS192 Ridgeland - TR71 Matrl
4,002,559
36
OCC Static Switch Repair
3,886,043
37
CyrusOne Aurora TR at TSS111
3,688,863
38
TSS78 Franklin Park L3705 PST
3,643,343
39
Prj Unity-138kV L0901 Brdg PWR
2,960,684
40
TDC 505 Oak Park Hardening
2,925,803
41
STA11 Fisk Cap Bank
2,754,808
42
TSS 76 Blue Island 345 kV Expa
2,567,600
43
L2105 Line Rebuild
2,474,919
44
L19414 S. Pecatonic break
1,857,586
45
L17105 Wood Pole Replacement
1,724,984
46
L17401 Leak Repair
1,699,539
47
Pine TUG 138kV L10108-T
1,521,950
48
Pine TUG 138kV L10109-T
1,519,437
49
L17113 Wood Pole Replacement
1,499,167
50
L19414 Wood Pole Replacement
1,482,089
51
TSS37 Natoma 138kV Hardening
1,455,426
52
TSS242 Greenleaf Station Build
1,405,098
53
TSS184 Elk Grove 345kV TR 81
1,381,378
54
NTT Data Center - TSS101-T
1,357,864
55
GIS Building - TSS51 138kV GIS
1,338,280
56
TSS101 Itasca 138kV Cap Bank
1,279,383
57
362439 TSS 300 Keslinger 138kV
1,191,424
58
TSS110 Devon 138kV Hardening
1,178,214
59
TSS184 Elk Grove-345kV TR 82
1,143,702
60
L7615 Wood Replacement
1,098,891
61
Auto Transformers at TSS192
1,098,705
62
TSS 146 Sandwich 138kV Station
1,075,059
63
Rebuild 69SK6
1,057,225
64
TSS177 Burnham TR84 Replacemen
1,039,008
65
Other Projects - 1
(b)
36,909,533
66
Distribution Plant
67
Major Projects:
68
Cloud HQ Data Center-ESSE410
26,537,475
69
Project Post - ESS E 535
25,411,092
70
TSS 82 Crosby Intel Sub
24,446,336
71
Aligned Data Cented 505 NW
17,136,323
72
Project Circle ESSE552
17,006,733
73
1680 E TOUHY
8,798,343
74
3P190201-Z11884
8,129,787
75
Retire 4kV Fdrs W405 W406 W438
7,936,741
76
CyrusOne Wood Dale -ESS
7,604,259
77
CyrusOne Aurora TR at TSS111 - 1
7,503,007
78
TSS64 Bellwood 12kV Switchgear
7,130,147
79
TSS104 Ford City Intel Sub
6,570,544
80
Indirects-Removal for Budget
6,172,866
81
TSS 181 Compass Data Center
6,127,641
82
Stream Data Center
5,929,709
83
NTT Data Center ESS
5,737,497
84
Project Post - L21408
5,729,710
85
4P223700-DCE27 Arlington Hts’
5,251,044
86
L1863/L1864/L1865 Relocation
4,994,455
87
Microsoft CHI07 Data Center
4,975,120
88
Aligned ESS at Elk Grove
4,767,499
89
Project Post - L21403
4,687,161
90
National Digital Gateway ESS
4,623,054
91
L19203 HPFF Replacement
4,405,045
92
Spare TR67MVA (3-Wind)Aligned
4,397,392
93
MediterraneanDataCenter-L18402
4,291,343
94
MediterraneanDataCenter-L18409
4,271,245
95
5P2302: new feeder D3429
3,925,475
96
77698:7P230001-TSS113 UPG Dist
3,848,593
97
Prime Data Center Trans/34KV
3,806,957
98
6P230800 - 4:12 conversions
3,738,245
99
New Feeder Z17449
3,365,887
100
2021 REACTS STA13 FOH
3,289,654
101
3P211002-56TH144 12 KV CONV
2,974,272
102
362780: STATE & LAKE/CDOT ZN1
2,957,700
103
Project Circle NEW ESS
2,944,266
104
CSX Midway Airport L5103 Reloc
2,938,110
105
1P240004- Replace 69kV bus
2,926,294
106
L13349- River Crossing INS CBL
2,822,799
107
1P190001-Install 5th TR
2,809,259
108
1050 W. Van Buren - Perm
2,707,588
109
7P240001-TDC375 new trans
2,701,421
110
505 Northwest - Phase 2
2,668,879
111
Northpoint Elwood Phase 2
2,656,441
112
MR 2022 1300 GROUP NETCENTERS
2,483,429
113
2021 REACTS STA13_2 FOH
2,365,642
114
8P250001 TDC446 Lansing 12kV
2,201,753
115
Iron Mountain TSS46 DesPlaines
2,152,467
116
Spare TR 40MVA (2-Wind) Ridgld
2,059,444
117
34kV Resiliency-L19342 Part 1
2,035,205
118
12 kV DA Baseline X1492
2,028,218
119
7P230800 - B169
1,994,715
120
Yukon Proj-Walmart ColdStorage
1,982,410
121
TSS192 Ridgeland TR71 Replcmnt
1,932,333
122
Prime Data Center Elk Grove
1,849,339
123
1P250001-New Rockwell TDC
1,831,348
124
RT 53 & RT 56 DUPAGE COUNTY
1,778,723
125
6P240007 TSS149 12kV
1,676,460
126
STREAM 1 ADD SERVICE
1,620,970
127
Project Barb_PD_7P231400
1,584,802
128
NB 1501 SOUTH WELLS PERM
1,584,177
129
TSS184 Third TR
1,536,185
130
Edged Energy Data Center - ESS
1,519,999
131
12 kV DA IP2 X3980
1,510,834
132
1P240400 SC Work on X4866X
1,506,638
133
ITN 362197: Woodstock IL 47
1,504,288
134
GRIP 2016 12kV Y8256
1,480,343
135
644 Madison, Oak Park - Perm
1,449,538
136
1955 W Hastings - PERM
1,440,104
137
5P230001 TSS131 Bus Exp
1,427,707
138
520 S MAPLE
1,376,761
139
362293 :FR-S ELGIN S MCLEAN BL
1,375,072
140
12 kV DA X8442
1,369,254
141
12kV DA Program - Z17450
1,317,674
142
PQ Meters
1,316,936
143
Compass TUG 138kV L18517
1,312,425
144
1P250200-New fdr to rlv TSS84
1,278,533
145
CyrusOne ButterfieldDataCenter
1,276,044
146
TDC452 Replace TR71
1,235,805
147
363158:Orland Park- IL 7/South
1,233,621
148
362342 : Lisle, Warrenville Rd
1,223,338
149
8001 W Belmont - Phase 2 & 3
1,191,128
150
28 E Garfield-Washington Park
1,172,648
151
8P233700 4:12kV G53 & G56
1,170,397
152
220 E Illinois Station Relief
1,166,927
153
3P240200 : New Fdr Z1412
1,161,373
154
KARE ESS
1,160,541
155
5P220402 Boring D3427 feeder
1,128,884
156
PD# 1P241000 - NETWORK TIES
1,107,479
157
1P240410-Relieve X1496
1,106,089
158
Spare TR 40MVA TSS141-2
1,092,457
159
Spare TR 40MVA  TSS141
1,092,457
160
SBA EDGE LINE EXTENSION
1,084,106
161
3P230200: Long lead NSC
1,072,594
162
Spare TR 50MVA (Compct) E Frkf
1,054,562
163
917 W Fulton - Perm Service
1,052,268
164
PD# 3P233700 IP2 4/12kV THRP42
1,032,207
165
12kV DA Program - X8443
1,013,422
166
CloudHQ - E524 & E5220 Feeder
1,008,560
167
Other Projects - 2
(c)
196,113,710
168
General Plant
169
2020 REACTS STA18-TSS60 DFR
7,176,165
170
2019 REACTS TSS157-DCK15 BBF
6,744,927
171
REACTS 1C224302 TSS30-TSS30-03
6,117,523
172
Maywood Lab expansion
5,634,755
173
HEALTH - Analytics DAP HW
3,839,477
174
EUN Refresh 2023 HW
3,815,649
175
REACTS DF-TSS89-TSS118-LINK 2
3,609,955
176
2019 REACTS STA22-STA16 BBF
3,488,408
177
2020 REACTS TSS193-TSS193 DFR
3,365,062
178
2021 REACTS DF-STA13-STA13-01
3,315,185
179
REACTS DIXON BBF LINK 5
3,044,292
180
Long Term Performance Plan
2,921,206
181
Long Term Performance Plan - 1
2,608,100
182
2020 REACTS TSS60-TDC461-2 DFR
2,571,397
183
REACTS 1C224303TDC714-TDC714-1
2,521,611
184
Long Term Performance Plan - 2
2,496,120
185
Long Term Performance Plan - 3
2,439,658
186
Long Term Performance Plan - 4
2,401,723
187
REACTS1C224303 TDC714-TDC714-2
2,372,134
188
Long Term Performance Plan - 5
2,289,454
189
2019 REACTS TDC294-TSS154 BBF
2,263,942
190
Long Term Performance Plan - 6
2,227,485
191
Long Term Performance Plan - 7
2,154,675
192
Long Term Performance Plan - 8
2,145,482
193
2020 REACTS TDC447 to TSS73
2,093,062
194
2019 REACTS TSS945-TSS70 BBF
2,028,659
195
ADMS Task Force - HW
1,936,991
196
Project Post - ESS E 535 - 1
1,821,157
197
NORTH VO TDC212 NORTHBROOK
1,782,072
198
REACTS CRE BBF LINK 1
1,761,156
199
Long Term Performance Plan - 9
1,709,513
200
ATO Monitoring- Chicago
1,673,773
201
2020 REACTS TDC409-TSS474 BFR
1,561,765
202
2020 REACnTS TDC206
1,505,477
203
REACTS1C224303 TDC714-TDC714-4
1,475,194
204
Chicago North EVCS 2023
1,456,651
205
Long Term Performance Plan - 10
1,440,326
206
Private LTE Cores & Initia HW
1,406,040
207
FIBER TSS160-TSS165-01.01 ROC
1,368,137
208
2019 REACTS STA16-TDC294 BBF
1,289,117
209
REACTS 1C224302 STA13-TSS30-01
1,209,273
210
Long Term Performance Plan - 11
1,194,545
211
2021 REACTS BF-TDC469-TDC531
1,173,639
212
2021 REACTS DF-STA13_2-TSS63-1
1,166,886
213
2020 REACTS BF-SS851-SS895
1,166,718
214
REACTS 1C224302 TSS30-TSS30-1
1,164,147
215
2020 REACTS BF-TSS63-SS851
1,157,691
216
REACTS 1C224302 TSS30-TSS38-01
1,146,251
217
SS674 12kV Relay Upgd SCADA
1,107,198
218
S211 - Customer Target BESS
1,089,910
219
2021 REACTS DF-STA13-STA13_2-2
1,072,343
220
2020 REACTS DF-TSS60-TSS115-01
1,056,660
221
S385 - Customer Target BESS
1,028,970
222
2019 REACTS TSS86 to TSS946 BB
1,015,093
223
Other Projects - 3
(d)
62,664,922
43
Total
1,220,404,574


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: ConstructionWorkInProgress
There are 33 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.
(b) Concept: ConstructionWorkInProgress
There are 450 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.
(c) Concept: ConstructionWorkInProgress
There are 2,555 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.
(d) Concept: ConstructionWorkInProgress
There are 543 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
  1. Explain in a footnote any important adjustments during year.
  2. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property.
  3. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications.
  4. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.
Item
(a)
Total (c + d + e)
(b)
Electric Plant in Service
(c)
Electric Plant Held for Future Use
(d)
Electric Plant Leased To Others
(e)
Section A. Balances and Changes During Year
1
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance Beginning of Year
10,663,341,920
10,663,341,920
2
Depreciation Provisions for Year, Charged to
3
DepreciationExpenseExcludingAdjustments
(403) Depreciation Expense
1,052,277,392
1,052,277,392
4
DepreciationExpenseForAssetRetirementCosts
(403.1) Depreciation Expense for Asset Retirement Costs
1,830,160
1,830,160
5
ExpensesOfElectricPlantLeasedToOthers
(413) Exp. of Elec. Plt. Leas. to Others
6
TransportationExpensesClearing
Transportation Expenses-Clearing
30,881,681
30,881,681
7
OtherClearingAccounts
Other Clearing Accounts
8
OtherAccounts
Other Accounts (Specify, details in footnote):
9.1
Other Accounts (Specify, details in footnote):
5,143,225
(a)
5,143,225
10
DepreciationProvision
TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)
1,090,132,458
1,090,132,458
11
Net Charges for Plant Retired:
12
BookCostOfRetiredPlant
Book Cost of Plant Retired
315,979,540
(b)
315,979,540
13
CostOfRemovalOfPlant
Cost of Removal
157,100,973
157,100,973
14
SalvageValueOfRetiredPlant
Salvage (Credit)
4,504,001
4,504,001
15
NetChargesForRetiredPlant
TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)
468,576,512
468,576,512
16
OtherAdjustmentsToAccumulatedDepreciation
Other Debit or Cr. Items (Describe, details in footnote):
17.1
Other Debit or Cr. Items (Describe, details in footnote):
4,125,984
(c)
4,125,984
18
BookCostOfAssetRetirementCosts
Book Cost or Asset Retirement Costs Retired
517,782
517,782
19
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)
11,280,254,100
11,280,254,100
Section B. Balances at End of Year According to Functional Classification
20
AccumulatedDepreciationSteamProduction
Steam Production
21
AccumulatedDepreciationNuclearProduction
Nuclear Production
22
AccumulatedDepreciationHydraulicProductionConventional
Hydraulic Production-Conventional
23
AccumulatedDepreciationHydraulicProductionPumpedStorage
Hydraulic Production-Pumped Storage
24
AccumulatedDepreciationOtherProduction
Other Production
25
AccumulatedDepreciationTransmission
Transmission
1,859,483,326
1,859,483,326
26
AccumulatedDepreciationDistribution
Distribution
7,979,349,453
7,979,349,453
27
AccumulatedDepreciationRegionalTransmissionAndMarketOperation
Regional Transmission and Market Operation
28
AccumulatedDepreciationGeneral
General
1,441,421,321
(d)
1,441,421,321
29
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
TOTAL (Enter Total of lines 20 thru 28)
11,280,254,100
11,280,254,100


FOOTNOTE DATA

(a) Concept: OtherAccounts
Accumulated Depreciation on asset retirement costs charged primarily to Account 182.3 $ 5,143,225 
(b) Concept: BookCostOfRetiredPlant
Retirements per Page 219 for Account 108 $ 315,979,540 
Retirements per Page 204 for Plant in Service 569,201,164 
Difference $ 253,221,624 
Details of Difference:
Retirement of Asset Retirement Costs for FIN 47 $ 517,782 
Retirement of Leasehold improvements charged to Account 111 - Accumulated Provisions for Amortization 4,705,757 
Retirement of Software charged to Account 111 247,998,085 
Total $ 253,221,624 
(c) Concept: OtherAdjustmentsToAccumulatedDepreciation
Adjustments to Account 108 - Accumulated Provision for Depreciation - for revisions recorded to the Asset Retirement Obligations and ARO Regulatory Assets $ (4,125,984)
(d) Concept: AccumulatedDepreciationGeneral
The amount of accumulated depreciation associated with Account 397 (Communication Equipment) as of December 31, 2024 is $889,067,578 - 30.18% of such amount is directly assignable to the Transmission function, and 69.82% of such amount is directly assignable to the Distribution function

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
  1. Report below investments in Account 123.1, Investments in Subsidiary Companies.
  2. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal.
  3. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1.
  4. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge.
  5. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number.
  6. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year.
  7. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f).
  8. Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.
DescriptionOfInvestmentsInSubsidiaryCompanies
Description of Investment
(a)
DateOfAcquisitionInvestmentsInSubsidiaryCompanies
Date Acquired
(b)
DateOfMaturityInvestmentsInSubsidiaryCompanies
Date of Maturity
(c)
InvestmentInSubsidiaryCompanies
Amount of Investment at Beginning of Year
(d)
EquityInEarningsOfSubsidiaryCompanies
Equity in Subsidiary Earnings of Year
(e)
InterestAndDividendRevenueFromInvestments
Revenues for Year
(f)
InvestmentInSubsidiaryCompanies
Amount of Investment at End of Year
(g)
InvestmentGainLossOnDisplosal
Gain or Loss from Investment Disposed of
(h)
1
Commonwealth Edison Company of Indiana, Inc.
12/31/1962
2
Common Stock, no par value (III. C.C. Docket Number 46967)
6,189,528
6,189,528
3
Other Capital Stock Transactions - Net
34,161,813
34,161,813
4
Undistributed Earnings
55,676,181
8,756,536
4,837,864
59,594,853
5
Subtotal
96,027,522
8,756,536
4,837,864
99,946,194
6
ComEd Financing III
7
Common Securities (III. C. C. Docket Number 02-0562)
6,186,000
6,186,000
8
Undistributed Earnings
115,661
392,811
392,811
115,661
9
Subtotal
6,301,661
392,811
392,811
6,301,661
10
EdiSun, LLC
11
Ownership Interest
61,592
61,592
12
RITELine Illinois, LLC
13
Ownership Interest
20,537
20,537
42
Total Cost of Account 123.1 $
12,375,528
Total
102,288,128
9,149,347
5,230,675
106,206,800


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
MATERIALS AND SUPPLIES
  1. For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material.
  2. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.
Account
(a)
Balance Beginning of Year
(b)
Balance End of Year
(c)
Department or Departments which Use Material
(d)
1
Fuel Stock (Account 151)
2
Fuel Stock Expenses Undistributed (Account 152)
3
Residuals and Extracted Products (Account 153)
4
Plant Materials and Operating Supplies (Account 154)
5
Assigned to - Construction (Estimated)
268,199,577
(a)
181,978,717
6
Assigned to - Operations and Maintenance
7
Production Plant (Estimated)
8
Transmission Plant (Estimated)
4,642,775
7,595,643
Transmission
9
Distribution Plant (Estimated)
12,718,935
108,115,374
Distribution
10
Regional Transmission and Market Operation Plant (Estimated)
11
Assigned to - Other (provide details in footnote)
12
TOTAL Account 154 (Enter Total of lines 5 thru 11)
285,561,287
297,689,734
13
Merchandise (Account 155)
14
Other Materials and Supplies (Account 156)
15
Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)
16
Stores Expense Undistributed (Account 163)
17
18
19
20
TOTAL Materials and Supplies
285,561,287
297,689,734


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesConstruction
Assigned to - Construction (Estimated)
Transmission Plant (Estimated) $ 47,487,920 
Distribution Plant (Estimated) 134,490,797 
Assigned to - Construction (Estimated) $ 181,978,717 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts.
  4. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k).
  5. Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances.
  7. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
Current Year Year One Year Two Year Three Future Years Totals
Line No.
SO2 Allowances Inventory (Account 158.1)
(a)
No.
(b)
Amt.
(c)
No.
(d)
Amt.
(e)
No.
(f)
Amt.
(g)
No.
(h)
Amt.
(i)
No.
(j)
Amt.
(k)
No.
(l)
Amt.
(m)
1
Balance-Beginning of Year
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
5
Returned by EPA
6
7
8
9
10
11
12
13
14
15
Total
16
17
Relinquished During Year:
18
Charges to Account 509
19
Other:
20
Allowances Used
20.1
Allowances Used
21
Cost of Sales/Transfers:
22
23
24
25
26
27
28
Total
29
Balance-End of Year
30
31
Sales:
32
Net Sales Proceeds(Assoc. Co.)
33
Net Sales Proceeds (Other)
34
Gains
35
Losses
Allowances Withheld (Acct 158.2)
36
Balance-Beginning of Year
37
Add: Withheld by EPA
38
Deduct: Returned by EPA
39
Cost of Sales
40
Balance-End of Year
41
42
Sales
43
Net Sales Proceeds (Assoc. Co.)
44
Net Sales Proceeds (Other)
45
Gains
46
Losses


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
Allowances (Accounts 158.1 and 158.2)
  1. Report below the particulars (details) called for concerning allowances.
  2. Report all acquisitions of allowances at cost.
  3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts.
  4. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k).
  5. Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.
  6. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances.
  7. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts).
  8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies.
  9. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers.
  10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
Current Year Year One Year Two Year Three Future Years Totals
Line No.
NOx Allowances Inventory (Account 158.1)
(a)
No.
(b)
Amt.
(c)
No.
(d)
Amt.
(e)
No.
(f)
Amt.
(g)
No.
(h)
Amt.
(i)
No.
(j)
Amt.
(k)
No.
(l)
Amt.
(m)
1
Balance-Beginning of Year
2
3
Acquired During Year:
4
Issued (Less Withheld Allow)
5
Returned by EPA
6
7
8
9
10
11
12
13
14
15
Total
16
17
Relinquished During Year:
18
Charges to Account 509
19
Other:
20
Allowances Used
20.1
Allowances Used
21
Cost of Sales/Transfers:
22
23
24
25
26
27
28
Total
29
Balance-End of Year
30
31
Sales:
32
Net Sales Proceeds(Assoc. Co.)
33
Net Sales Proceeds (Other)
34
Gains
35
Losses
Allowances Withheld (Acct 158.2)
36
Balance-Beginning of Year
37
Add: Withheld by EPA
38
Deduct: Returned by EPA
39
Cost of Sales
40
Balance-End of Year
41
42
Sales
43
Net Sales Proceeds (Assoc. Co.)
44
Net Sales Proceeds (Other)
45
Gains
46
Losses


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
WRITTEN OFF DURING YEAR
Line No.
DescriptionOfExtraordinaryPropertyLoss
Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).]
(a)
ExtraordinaryPropertyLossesNotYetRecognized
Total Amount of Loss
(b)
ExtraordinaryPropertyLossesRecognized
Losses Recognized During Year
(c)
ExtraordinaryPropertyLossesWrittenOffAccountCharged
Account Charged
(d)
ExtraordinaryPropertyLossesWrittenOff
Amount
(e)
ExtraordinaryPropertyLosses
Balance at End of Year
(f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
20 TOTAL


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
WRITTEN OFF DURING YEAR
Line No.
DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts
Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)]
(a)
UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized
Total Amount of Charges
(b)
UnrecoveredPlantAndRegulatoryStudyCostsRecognized
Costs Recognized During Year
(c)
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged
Account Charged
(d)
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff
Amount
(e)
UnrecoveredPlantAndRegulatoryStudyCosts
Balance at End of Year
(f)
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
TOTAL


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
Transmission Service and Generation Interconnection Study Costs
  1. Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies.
  2. List each study separately.
  3. In column (a) provide the name of the study.
  4. In column (b) report the cost incurred to perform the study at the end of period.
  5. In column (c) report the account charged with the cost of the study.
  6. In column (d) report the amounts received for reimbursement of the study costs at end of period.
  7. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.
DescriptionOfStudyPerformed
Description
(a)
StudyCostsIncurred
Costs Incurred During Period
(b)
StudyCostsAccountCharged
Account Charged
(c)
StudyCostsReimbursements
Reimbursements Received During the Period
(d)
StudyCostsAccountReimbursed
Account Credited With Reimbursement
(e)
1
Transmission Studies
2
PJM AE1-070 Elwood 345 kV Faci
2,152
68,509
3
PJM AE1-070 Elwood 345 kV Faci
6,832
4
PJM AE1-070 Elwood 345 kV Faci
43,485
5
PJM AE1-070 Elwood 345 kV Faci
16,040
20
Total
68,509
68,509
21
Generation Studies
22
AE1-114 PJM Facilities Study
4,034
142,665
23
AE1-114 PJM Facilities Study
95,836
24
AE1-114 PJM Facilities Study
12,197
25
AE1-114 PJM Facilities Study
30,598
26
PJM AE2-173: MCLEAN 345 KV
2,191
74,397
27
PJM AE2-173: MCLEAN 345 KV
48,912
28
PJM AE2-173: MCLEAN 345 KV
6,741
29
PJM AE2-173: MCLEAN 345 KV
16,553
30
PJM AE2-341 Facility Study
3,531
133,062
31
PJM AE2-341 Facility Study
90,953
32
PJM AE2-341 Facility Study
10,797
33
PJM AE2-341 Facility Study
27,781
34
PJM AF1-030 Facility Study
2,178
74,109
35
PJM AF1-030 Facility Study
48,772
36
PJM AF1-030 Facility Study
6,714
37
PJM AF1-030 Facility Study
16,445
38
AF-2041 Nelson-Elec Junc 345kV
4,702
160,434
39
AF-2041 Nelson-Elec Junc 345kV
105,541
40
AF-2041 Nelson-Elec Junc 345kV
14,750
41
AF-2041 Nelson-Elec Junc 345kV
35,441
42
PJM AF2-128 Crescent Ridge-Cor
39
959
43
PJM AF2-128 Crescent Ridge-Cor
533
44
PJM AF2-128 Crescent Ridge-Cor
125
45
PJM AF2-128 Crescent Ridge-Cor
262
46
AF2-199 Nelson-Elec Junc 345kV
2,768
99,938
47
AF2-199 Nelson-Elec Junc 345kV
66,728
48
AF2-199 Nelson-Elec Junc 345kV
8,733
49
AF2-199 Nelson-Elec Junc 345kV
21,709
50
AF2-349 Garden Prairie 345 kV
3,859
132,307
51
AF2-349 Garden Prairie 345 kV
88,774
52
AF2-349 Garden Prairie 345 kV
11,605
53
AF2-349 Garden Prairie 345 kV
28,069
54
PJM MISO J955 FACILITIES STUDY
1,135
29,975
55
PJM MISO J955 FACILITIES STUDY
16,951
56
PJM MISO J955 FACILITIES STUDY
3,887
57
PJM MISO J955 FACILITIES STUDY
8,040
58
MISO J1377 - PJM Facilities
2,301
95,304
59
MISO J1377 - PJM Facilities
65,130
60
MISO J1377 - PJM Facilities
7,848
61
MISO J1377 - PJM Facilities
20,025
62
AF2-027 Facility Study
42
1,125
63
AF2-027 Facility Study
646
64
AF2-027 Facility Study
144
65
AF2-027 Facility Study
293
66
PJM AF2-363 Cherry Valley-Glid
169
4,480
67
PJM AF2-363 Cherry Valley-Glid
2,565
68
PJM AF2-363 Cherry Valley-Glid
578
69
PJM AF2-363 Cherry Valley-Glid
1,168
70
PJM AF1-090 Facilities Study
4,965
199,008
71
PJM AF1-090 Facilities Study
133,356
72
PJM AF1-090 Facilities Study
16,849
73
PJM AF1-090 Facilities Study
43,838
74
PJM AF2-366 Facilities Study
4,298
161,852
75
PJM AF2-366 Facilities Study
106,222
76
PJM AF2-366 Facilities Study
14,422
77
PJM AF2-366 Facilities Study
36,910
78
PJM AG1-512
42
1,086
79
PJM AG1-512
619
80
PJM AG1-512
141
81
PJM AG1-512
284
82
PJM AF2-031 Facility Study
300
10,710
83
PJM AF2-031 Facility Study
6,845
84
PJM AF2-031 Facility Study
1,036
85
PJM AF2-031 Facility Study
2,529
86
AF2-252 PJM Facilities Study
274
9,967
87
AF2-252 PJM Facilities Study
6,510
88
AF2-252 PJM Facilities Study
945
89
AF2-252 PJM Facilities Study
2,238
90
AF2-352 PJM Facilities Study
604
18,013
91
AF2-352 PJM Facilities Study
10,909
92
AF2-352 PJM Facilities Study
2,042
93
AF2-352 PJM Facilities Study
4,458
94
PJM J982 Facilities Study
2,548
93,380
95
PJM J982 Facilities Study
60,673
96
PJM J982 Facilities Study
8,644
97
PJM J982 Facilities Study
21,515
98
TC01-PJM Transition Cycle 1
30,271
687,845
99
TC01-PJM Transition Cycle 1
365,607
100
TC01-PJM Transition Cycle 1
97,343
101
TC01-PJM Transition Cycle 1
194,624
102
AF2-095 Wilmington-Davis Creek
2,912
96,192
103
AF2-095 Wilmington-Davis Creek
62,875
104
AF2-095 Wilmington-Davis Creek
8,922
105
AF2-095 Wilmington-Davis Creek
21,483
106
PJM AF2-392 Facilities Study
4,406
173,261
107
PJM AF2-392 Facilities Study
119,698
108
PJM AF2-392 Facilities Study
13,483
109
PJM AF2-392 Facilities Study
35,674
110
PJM AF2-441 Facilities Study
4,025
147,009
111
PJM AF2-441 Facilities Study
99,120
112
PJM AF2-441 Facilities Study
12,280
113
PJM AF2-441 Facilities Study
31,584
114
AE1-172 Loretto-Wilton Study
4,507
148,969
115
AE1-172 Loretto-Wilton Study
96,228
116
AE1-172 Loretto-Wilton Study
14,152
117
AE1-172 Loretto-Wilton Study
34,082
118
AE2-107 Haumesser Rd PJM Study
131
3,067
119
AE2-107 Haumesser Rd PJM Study
1,659
120
AE2-107 Haumesser Rd PJM Study
412
121
AE2-107 Haumesser Rd PJM Study
865
122
PJM AE2-223 McLean 345kV Facil
2,606
84,366
123
PJM AE2-223 McLean 345kV Facil
54,275
124
PJM AE2-223 McLean 345kV Facil
8,065
125
PJM AE2-223 McLean 345kV Facil
19,420
126
PJM AE2-261 Facilities Study
3,769
137,690
127
PJM AE2-261 Facilities Study
93,142
128
PJM AE2-261 Facilities Study
11,565
129
PJM AE2-261 Facilities Study
29,214
130
PJM AE2-321 Facilities Study
3,615
134,098
131
PJM AE2-321 Facilities Study
91,280
132
PJM AE2-321 Facilities Study
11,068
133
PJM AE2-321 Facilities Study
28,135
134
AF1-048 Belvidere Morengo
2,380
77,587
135
AF1-048 Belvidere Morengo
50,604
136
AF1-048 Belvidere Morengo
7,303
137
AF1-048 Belvidere Morengo
17,300
138
PJM AF1-200 Facilities Study
3,942
127,758
139
PJM AF1-200 Facilities Study
82,817
140
PJM AF1-200 Facilities Study
12,243
141
PJM AF1-200 Facilities Study
28,756
142
PJM AF1-252 Facilities Study
39
966
143
PJM AF1-252 Facilities Study
536
144
PJM AF1-252 Facilities Study
126
145
PJM AF1-252 Facilities Study
265
146
PJM AF1-253 Facilities Study
66
1,599
147
PJM AF1-253 Facilities Study
888
148
PJM AF1-253 Facilities Study
208
149
PJM AF1-253 Facilities Study
437
150
AF1-280 Nelson Lee County Stud
4,317
150,705
151
AF1-280 Nelson Lee County Stud
100,507
152
AF1-280 Nelson Lee County Stud
13,380
153
AF1-280 Nelson Lee County Stud
32,501
154
AF1-281 Nelson & Lee County
177
3,387
155
AF1-281 Nelson & Lee County
1,751
156
AF1-281 Nelson & Lee County
515
157
AF1-281 Nelson & Lee County
944
158
PJM AF1-296 Facilities Study
3,578
113,029
159
PJM AF1-296 Facilities Study
74,674
160
PJM AF1-296 Facilities Study
10,856
161
PJM AF1-296 Facilities Study
23,921
162
PJM AF1-314 Facilities Study
5,542
198,275
163
PJM AF1-314 Facilities Study
133,401
164
PJM AF1-314 Facilities Study
16,859
165
PJM AF1-314 Facilities Study
42,473
166
PJM AF1-318 Facilities Study
213
6,730
167
PJM AF1-318 Facilities Study
5,029
168
PJM AF1-318 Facilities Study
53
169
PJM AF1-318 Facilities Study
1,967
170
PJM AF2-034 Facilities Study
2,749
80,097
171
PJM AF2-034 Facilities Study
49,426
172
PJM AF2-034 Facilities Study
8,500
173
PJM AF2-034 Facilities Study
19,422
174
PJM AF2-069 Facilities Study
1,576
57,635
175
PJM AF2-069 Facilities Study
37,991
176
PJM AF2-069 Facilities Study
5,148
177
PJM AF2-069 Facilities Study
12,920
178
PJM AF2-070 Facilities Study
1,576
45,507
179
PJM AF2-070 Facilities Study
29,907
180
PJM AF2-070 Facilities Study
4,676
181
PJM AF2-070 Facilities Study
9,348
182
PJM AF2-096 Facilities Study
4,427
134,743
183
PJM AF2-096 Facilities Study
85,523
184
PJM AF2-096 Facilities Study
13,763
185
PJM AF2-096 Facilities Study
31,030
186
PJM AF2-142 Facilities Study
2,069
64,309
187
PJM AF2-142 Facilities Study
41,166
188
PJM AF2-142 Facilities Study
6,410
189
PJM AF2-142 Facilities Study
14,664
190
AF2-143 Powerton- Nevada 345kV
2,110
65,160
191
AF2-143 Powerton- Nevada 345kV
41,586
192
AF2-143 Powerton- Nevada 345kV
6,509
193
AF2-143 Powerton- Nevada 345kV
14,955
194
PJM AF2-182 Facilities Study
1,810
58,289
195
PJM AF2-182 Facilities Study
37,766
196
PJM AF2-182 Facilities Study
5,615
197
PJM AF2-182 Facilities Study
13,098
198
PJM AF2-183- Nelson Lee County
202
4,638
199
PJM AF2-183- Nelson Lee County
2,480
200
PJM AF2-183- Nelson Lee County
639
201
PJM AF2-183- Nelson Lee County
1,317
202
AF2-200 Nelson Elec Junc 345kV
2,731
99,799
203
AF2-200 Nelson Elec Junc 345kV
66,718
204
AF2-200 Nelson Elec Junc 345kV
8,621
205
AF2-200 Nelson Elec Junc 345kV
21,729
206
PJM AF2-201 Facilities Study
4,651
162,684
207
PJM AF2-201 Facilities Study
108,660
208
PJM AF2-201 Facilities Study
14,257
209
PJM AF2-201 Facilities Study
35,116
210
AF2-225 McLean 345kV
2,072
71,832
211
AF2-225 McLean 345kV
47,517
212
AF2-225 McLean 345kV
6,446
213
AF2-225 McLean 345kV
15,797
214
PJM AF2-226 Facilities Study
1,747
57,776
215
PJM AF2-226 Facilities Study
37,787
216
PJM AF2-226 Facilities Study
5,455
217
PJM AF2-226 Facilities Study
12,787
218
PJM AF2-319 Facilities Study
1,824
60,418
219
PJM AF2-319 Facilities Study
39,565
220
PJM AF2-319 Facilities Study
5,689
221
PJM AF2-319 Facilities Study
13,340
222
PJM AF2-350
2,833
97,354
223
PJM AF2-350
64,495
224
PJM AF2-350
8,685
225
PJM AF2-350
21,341
226
PJM AF2-393 Facilities Study
1,960
61,553
227
PJM AF2-393 Facilities Study
39,423
228
PJM AF2-393 Facilities Study
6,076
229
PJM AF2-393 Facilities Study
14,094
230
PJM AF2-394 Facilities Study
1,663
54,297
231
PJM AF2-394 Facilities Study
35,483
232
PJM AF2-394 Facilities Study
5,165
233
PJM AF2-394 Facilities Study
11,986
234
PJM AG1-005 Facilities Study
3,196
125,039
235
PJM AG1-005 Facilities Study
86,452
236
PJM AG1-005 Facilities Study
9,768
237
PJM AG1-005 Facilities Study
25,623
238
PJM AG1-118 Facilities Study
3,690
135,605
239
PJM AG1-118 Facilities Study
92,155
240
PJM AG1-118 Facilities Study
11,256
241
PJM AG1-118 Facilities Study
28,504
242
PJM AG1-120 Facilities Study
2,127
65,436
243
PJM AG1-120 Facilities Study
41,722
244
PJM AG1-120 Facilities Study
6,551
245
PJM AG1-120 Facilities Study
15,036
246
PJM AG1-127 Facilities Study
3,102
107,404
247
PJM AG1-127 Facilities Study
71,437
248
PJM AG1-127 Facilities Study
9,528
249
PJM AG1-127 Facilities Study
23,334
250
PJM AG1-236 Facilities Study
2,463
72,944
251
PJM AG1-236 Facilities Study
45,725
252
PJM AG1-236 Facilities Study
7,555
253
PJM AG1-236 Facilities Study
17,201
254
PJM AG1-298 Facilities Study
4,738
132,527
255
PJM AG1-298 Facilities Study
86,455
256
PJM AG1-298 Facilities Study
13,734
257
PJM AG1-298 Facilities Study
27,600
258
PJM AG1-374 Facilities Study
3,642
124,405
259
PJM AG1-374 Facilities Study
82,607
260
PJM AG1-374 Facilities Study
11,227
261
PJM AG1-374 Facilities Study
26,929
262
PJM AG1-434 Facilities Study
4,435
177,951
263
PJM AG1-434 Facilities Study
124,052
264
PJM AG1-434 Facilities Study
13,448
265
PJM AG1-434 Facilities Study
36,016
266
PJM AG1-435 Facilities Study
3,685
138,622
267
PJM AG1-435 Facilities Study
94,577
268
PJM AG1-435 Facilities Study
11,166
269
PJM AG1-435 Facilities Study
29,194
270
PJM AG1-460 Facilities Study
2,030
69,069
271
PJM AG1-460 Facilities Study
45,813
272
PJM AG1-460 Facilities Study
6,214
273
PJM AG1-460 Facilities Study
15,012
274
PJM AG1-462 Facilities Study
3,889
142,447
275
PJM AG1-462 Facilities Study
96,211
276
PJM AG1-462 Facilities Study
11,860
277
PJM AG1-462 Facilities Study
30,487
278
PJM AG1-535 Facilities Study
1,736
64,068
279
PJM AG1-535 Facilities Study
42,992
280
PJM AG1-535 Facilities Study
5,491
281
PJM AG1-535 Facilities Study
13,849
282
PJM AG1-553 Facilities Study
4,218
155,125
283
PJM AG1-553 Facilities Study
105,281
284
PJM AG1-553 Facilities Study
12,852
285
PJM AG1-553 Facilities Study
32,774
286
PJM Facilities Studies
2,682
56,385
287
PJM Facilities Studies
29,360
288
PJM Facilities Studies
8,923
289
PJM Facilities Studies
15,420
39
Total
6,478,457
6,478,422
40 Grand Total
6,546,966
6,546,931


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
OTHER REGULATORY ASSETS (Account 182.3)
  1. Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable.
  2. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes.
  3. For Regulatory Assets being amortized, show period of amortization.
CREDITS
Line No.
DescriptionAndPurposeOfOtherRegulatoryAssets
Description and Purpose of Other Regulatory Assets
(a)
OtherRegulatoryAssets
Balance at Beginning of Current Quarter/Year
(b)
IncreaseDecreaseInOtherRegulatoryAssets
Debits
(c)
OtherRegulatoryAssetsWrittenOffAccountCharged
Written off During Quarter/Year Account Charged
(d)
OtherRegulatoryAssetsWrittenOffRecovered
Written off During the Period Amount
(e)
OtherRegulatoryAssets
Balance at end of Current Quarter/Year
(f)
1
(a)
Capitalized Employee Incentive Payments
5,097,129
287,485
4,809,644
2
Deferred Asset Retirement Obligation Costs
104,466,505
9,658,857
1,815,755
112,309,607
3
Cash Flow Swap Settlement Costs
4,718,859
519,507
4,199,352
4
MGP Remediation Costs
286,207,129
18,612,815
29,517,318
275,302,626
5
Renewable Energy Swaps
133,632,802
1,464,305
3,678,237
131,418,870
6
AMI Meter Accelerated Depreciation
28,072,525
15,150,370
12,922,155
7
Carbon Mitigation Credit
672,543,020
719,900,940
1,213,188,860
179,255,100
8
Rate Case
5,221,171
6,796,828
3,004,500
9,013,499
9
Uncollectible Accounts Expense - Under Recovery
78,454,238
61,906,395
14,328,360
126,032,273
10
Distribution Service Costs
886,581,574
64,275,953
215,393,053
735,464,474
11
Energy Efficiency Costs
1,691,436,816
435,219,508
236,797,267
1,889,859,057
12
Capital Lease Excess Depreciation
1,809,785
145,634
1,955,419
13
Purchased Receivables Program - Under Recovery
14,376,844
14,081,778
69,632
28,388,990
14
Purchased Electricity - Under Recovery
15,412,326
17,502,293
32,914,619
15
Distributed Generation Rebate Costs
108,432,814
74,269,943
10,921,831
171,780,926
16
Transmission Costs - Under Recovery
14,804,278
4,792,912
19,597,190
17
Parallel Operation of Retail Customer Generating Facilities Community Supply
2,872,854
2,872,854
18
Zero Emissions Program
58,111,921
54,603,205
3,508,716
19
Deferred Income Taxes
284,311,635
6,593,399
290,905,034
20
Interval Meter Usage Data
23,618
23,618
44
TOTAL
4,396,564,225
1,435,245,178
1,835,062,853
3,996,746,550


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets
Line Item Rate Order Docket Number Or Recovery Mechanism Amortization Period
Capitalized Employee Incentive Payments ICC Docket 01-0423 3/31/2003 - 7/31/2043
Deferred Asset Retirement Obligation Costs Rider DSPR, Multi-Year Rate Plan & Transmission Formula Rate Over the life of related assets
Cash Flow Swap Settlement Costs Rider DSPR, Multi-Year Rate Plan & Transmission Formula Rate 3/15/2002 - 1/31/2033
MGP Remediation Costs ICC Docket 05-0597 1/1/2007 - 12/31/2025
Renewable Energy Swaps ICC Docket No. 09-0373 6/1/2012 - 5/1/2032
AMI Meter Accelerated Depreciation ICC Docket 12-0298 1/1/2014-12/31/2028
Carbon Mitigation Credit CEJA 4 months from period end
Rate Case CEJA 4 years (2024 - 2027)
Uncollectible Accounts Expense - Under Recovery ICC Docket No. 09-0433 & 20-0309 12 months from each June
Distribution Service Costs EIMA & FEJA
SB2408 - Clean Energy Law - Distribution Formula Transition for year 2022 & 2023
3-5 years
Energy Efficiency Costs FEJA Over the measurable life of efficiency measures
Capital Lease Excess Depreciation Rider DSPR & Multi-Year Rate Plan 2039 - 2053
Purchased Receivables Program - Under Recovery ICC Docket 10-0138 1/1/2011 - 12/31/2020
Purchased Electricity - Under Recovery ICC Docket No. 05-0159 & 18-1824 4 months from period end
Distributed Generation Rebate Costs FEJA 15 years
Transmission Costs - Under Recovery FERC Docket ER07-583 12 months from each June
Parallel Operation of Retail Customer Generating Facilities Community Supply ICC Docket 22-0305 Not determined yet
Zero Emissions Program FEJA 9 months from each September
Interval Meter Usage Data ICC Docket 23-0773 6/1/2025 - 3/31/2030
Deferred Income Taxes ICC Order 18-0034 / FERC Order ER19-5 dated 4/26/2019 Over the life of related assets

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
MISCELLANEOUS DEFFERED DEBITS (Account 186)
  1. Report below the particulars (details) called for concerning miscellaneous deferred debits.
  2. For any deferred debit being amortized, show period of amortization in column (a)
  3. Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
CREDITS
Line No.
Description of Miscellaneous Deferred Debits
(a)
Balance at Beginning of Year
(b)
Debits
(c)
Credits Account Charged
(d)
Credits Amount
(e)
Balance at End of Year
(f)
1
Accumulated under/Over recoveries -local government compliance causes
398,120
1,286,205
1,357,765
326,560
2
Vacation pay and payroll taxes pending proper accounting distribution
25,782,540
309,790,361
312,895,407
22,677,494
3
Long-Term contracting services
288,672
112,973
195,369
206,276
4
Cook County Forest Preserve District License Fees to be amortized through 2027
3,342,361
685,683
2,656,678
5
Pension Asset
1,217,181,252
6,501,392
58,964,313
1,164,718,331
6
Long Term receivable from Constellation Energy Generation, LLC (formerly Exelon Generation Company, LLC) (SFAS 143, Regulatory Liability offset)
2,954,412,180
1,165,933,958
340,678,976
3,779,667,162
7
Long Term receivable from the MBA Plan
2,734,498
80,565,407
80,198,059
3,101,846
8
Credit facilities - ICC fees and other issuance costs to be amortized through 2027
303,598
1,653,241
657,207
1,299,632
9
ICC Financing Authority Fees
5,681,803
287,820
1,607,820
4,361,803
10
Insurance recoveries related to third party claims
7,230,846
31,379,255
6,503,849
32,106,252
11
Estimated Illinois Distribution Tax Refund
4,061,217
9,114,211
4,208,612
8,966,816
12
Long Term Restricted Cash
173,548,216
39,010,807
171,913,575
40,645,448
13
Long-Term Receivable Related to the FERC 494 Refund
5,278,640
5,278,640
14
Microgrid Prepayment
364,239
5,099,287
75,322
5,388,204
15
Adjustable Block REC Prepayments
575,273,878
297,864,958
11,697
873,127,139
16
Long-term portion of receivables from deferred payment agreements
1,389,745
1,735,644
3,010,047
115,342
17
Rochelle Franchise Fees to be amortized through 2070
1,380,000
30,000
1,350,000
18
Illinois Solar for All Program REC Prepayment
14,966,782
19,833,898
918,583
33,882,097
19
REACTS Fiber Program
139,337
119,913
19,424
20
Skydio Cloud 3yr Subscription Purchase
93,712
93,712
21
I&M Canal Fees to be amortized through June 2033
430,100
50,600
379,500
22
Maywood Outdoor Lab Program
816,074
206,501
582,796
439,779
23
Minor Items
2,141,210
481,686,774
481,930,265
1,897,719
47
Miscellaneous Work in Progress
228,940
208,872
48
Deferred Regulatory Comm. Expenses (See pages 350 - 351)
49
TOTAL
4,997,467,960
5,977,542,374


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged
Accumulated under/over recoveries are offset in Accounts 107000, 108030, 535250, 615000, 143300,410090, 131000, 232100, and 503000.
(b) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged
Minor items are offset in Accounts 107000, 131100, 182890, 184100, 184200, 228200, 232000, 232900, 241000, 242000, 242200, 242300, 514000, 514062, 517010, 535000, 535160 and 535170.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
ACCUMULATED DEFERRED INCOME TAXES (Account 190)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes.
  2. At Other (Specify), include deferrals relating to other income and deductions.
Line No.
DescriptionOfAccumulatedDeferredIncomeTax
Description and Location
(a)
AccumulatedDeferredIncomeTaxes
Balance at Beginning of Year
(b)
AccumulatedDeferredIncomeTaxes
Balance at End of Year
(c)
1
Electric
2
(a)
1,006,863,343
871,112,133
7
Other
8
TOTAL Electric (Enter Total of lines 2 thru 7)
1,006,863,343
(b)
871,112,133
9
Gas
15
Other
16
TOTAL Gas (Enter Total of lines 10 thru 15)
17.1
Other (Specify)
17
Other (Specify)
18
TOTAL (Acct 190) (Total of lines 8, 16 and 17)
1,006,863,343
871,112,133
Notes


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxes
Account 190 Federal Inc. Activity:
410 Debits $ 85,465,050 
411 Credits 25,632,926 
Net Debit/(Credits) $ 59,832,124 
Account 190 State Inc. Activity:
410 Debits $ 6,936,701 
411 Credits 12,813,090 
Net Debit/(Credits) $ (5,876,389)
Account 190 Activity B/S Only:
Debits $ — 
Credits 81,795,475 
Net Adjustments $ (81,795,475)
Net Change $ (135,751,210)
(b) Concept: AccumulatedDeferredIncomeTaxes
Account 190 Description: Beginning Balance Ending Balance
Accrued Benefits $ 4,018,069  $ 41,203,399 
Accrued Bonuses & Incentives 43,529,546  1,653,695 
Accrued Legal 14,253  — 
Accrued Severance 1,019,238  1,875,484 
Accrued Vacation 10,314,195  11,573,641 
Accrued Workers' Compensation 22,654,211  34,389,182 
Accrued OPEB 47,474,964  46,188,384 
Allowance for Doubtful Accounts 23,640,736  38,936,707 
Charitable Contribution Carryforward —  — 
Corporate Alternative Minimum Tax 118,023,568  47,215,886 
Deferred Compensation 8,499,188  8,237,241 
Deferred Revenue 2,405,758  2,114,350 
Environmental Cleanup Costs 13,150,719  161,707 
Manufactured Gas Plants 73,091,938  80,959,200 
Obsolete Materials 1,809,907  1,311,768 
Other - 190 9,892,629  10,542,851 
Regulatory Liability 620,745,033  539,101,260 
State Income Taxes 4,294,062  3,513,745 
Unamortized Investment Tax Credit 2,285,329  2,133,633 
Total $ 1,006,863,343  $ 871,112,133 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
CAPITAL STOCKS (Account 201 and 204)
  1. Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible.
  2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year.
  3. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued.
  4. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative.
  5. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year.
  6. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.
Class and Series of Stock and Name of Stock Series
(a)
Number of Shares Authorized by Charter
(b)
Par or Stated Value per Share
(c)
Call Price at End of Year
(d)
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares
(e)
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount
(f)
Held by Respondent As Reacquired Stock (Acct 217) Shares
(g)
Held by Respondent As Reacquired Stock (Acct 217) Cost
(h)
Held by Respondent In Sinking and Other Funds Shares
(i)
Held by Respondent In Sinking and Other Funds Amount
(j)
1
Common Stock (Account 201)
2
(a)
Total Common Stock
250,000,000
12.50
127,021,417
1,587,297,245
7
Total
250,000,000
127,021,417
1,587,297,245
8
Preferred Stock (Account 204)
9
10
11
12
Total


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: CapitalStockDescription
ComEd had 59,970 and 60,032 warrants outstanding to purchase ComEd common stock at December 31, 2024 and 2023, respectively. The warrants entitle the holders to convert such warrants into common stock of ComEd at a conversion rate of one share of common stock for three warrants. At December 31, 2024 and 2023, 19,990 and 20,011 shares of common stock, respectively, were reserved for the conversion of warrants.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2024-12-31
Year/Period of Report

End of:
2024
/
Q4
Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change.
  1. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation.
  2. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related.
  3. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related.
  4. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.
Item
(a)
Amount
(b)
1
DonationsReceivedFromStockholdersAbstract
Donations Received from Stockholders (Account 208)
2
DonationsReceivedFromStockholders
Beginning Balance Amount
3.1
IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders
Increases (Decreases) from Sales of Donations Received from Stockholders
4
DonationsReceivedFromStockholders
Ending Balance Amount
5
ReductionInParOrStatedValueOfCapitalStockAbstract
Reduction in Par or Stated Value of Capital Stock (Account 209)
6
ReductionInParOrStatedValueOfCapitalStock
Beginning Balance Amount
7.1
IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock
Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8
ReductionInParOrStatedValueOfCapitalStock
Ending Balance Amount
9
GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract
Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10
GainOnResaleOrCancellationOfReacquiredCapitalStock
Beginning Balance Amount
11.1
IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock
Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12
GainOnResaleOrCancellationOfReacquiredCapitalStock
Ending Balance Amount
13
MiscellaneousPaidInCapitalAbstract
Miscellaneous Paid-In Capital (Account 211)
14
MiscellaneousPaidInCapital
Beginning Balance Amount
5,388,756,067
15.1
IncreasesDecreasesDueToMiscellaneousPaidInCapital
Increases (Decreases) Due to Warrants
(a)
687
15.2
IncreasesDecreasesDueToMiscellaneousPaidInCapital
Increases (Decreases) Due to Miscellaneous Paid-In Capital
226,556,660
16
MiscellaneousPaidInCapital
Ending Balance Amount
(b)
5,615,312,040
17
OtherPaidInCapitalAbstract
Other Paid in Capital
18
OtherPaidInCapitalDetail
Beginning Balance Amount
19.1
IncreasesDecreasesInOtherPaidInCapital
Increases (Decreases) in Other Paid-In Capital
20
OtherPaidInCapitalDetail
Ending Balance Amount
40
OtherPaidInCapital
Total
5,615,312,040


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2024-12-31
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: IncreasesDecreasesDueToMiscellaneousPaidInCapital
These amounts represent the balances related to the following types of Common Stock Purchase Warrants:
Beginning Balance as of 12/31/2023 2024 YTD Activity Ending Balance as of 12/31/2024
1971 Warrants 525,811  (26) 525,785 
Series B Warrants 227,150  (661) 226,489 
Total Warrants 752,961   (687) 752,274  
(b) Concept: MiscellaneousPaidInCapital
The ending balance is comprised of $752,274 for Common Stock Purchase Warrants and $5,614,559,766 of other paid in capital. This other paid in capital amount represents the other paid in capital recognized from the indemnification from Exelon Corporation, the Respondent's parent, in related to the like-kind exchange transaction and to support expanded capital programs. See Note 7 - Income Taxes of the Notes to Financial Statements for additional information related to the like-kind exchanges.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
CAPITAL STOCK EXPENSE (Account 214)
  1. Report the balance at end of the year of discount on capital stock for each class and series of capital stock.
  2. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.
NameOfClassAndSeriesOfStock
Class and Series of Stock
(a)
CapitalStockExpense
Balance at End of Year
(b)
1
Common Stock
6,942,925
22
TOTAL
6,942,925


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
LONG-TERM DEBT (Account 221, 222, 223 and 224)
  1. Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt.
  2. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number.
  3. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number.
  4. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number.
  5. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates.
  6. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge.
  7. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote.
  8. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies.
  9. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.
ClassAndSeriesOfObligationCouponRateDescription
Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates)
(a)
RelatedAccountNumber
Related Account Number
(b)
Principal Amount of Debt Issued
(c)
LongTermDebtIssuanceExpensePremiumOrDiscount
Total Expense, Premium or Discount
(d)
LongTermDebtIssuanceExpenses
Total Expense
(e)
LongTermDebtPremium
Total Premium
(f)
LongTermDebtDiscount
Total Discount
(g)
NominalDateOfIssue
Nominal Date of Issue
(h)
DateOfMaturity
Date of Maturity
(i)
AmortizationPeriodStartDate
AMORTIZATION PERIOD Date From
(j)
AmortizationPeriodEndDate
AMORTIZATION PERIOD Date To
(k)
Outstanding (Total amount outstanding without reduction for amounts held by respondent)
(l)
Interest for Year Amount
(m)
1
Bonds (Account 221)
2
100, 5.875%
350,000,000
3,525,036
1,526,000
01/22/2003
02/01/2033
01/22/2003
02/01/2033
253,600,000
14,899,000
3
103, 5.900%
325,000,000
3,488,737
2,044,250
03/06/2006
03/15/2036
03/06/2006
03/15/2036
325,000,000
19,175,000
4
103B, 5.900%
300,000,000
1,048,534
12,435,000
03/22/2007
03/15/2036
03/22/2007
03/15/2036
300,000,000
17,700,000
5
107, 6.450%
450,000,000
4,468,683
1,359,000
01/16/2008
01/15/2038
01/16/2008
01/15/2038
450,000,000
29,025,000
6
113, 3.800%
350,000,000
3,497,084
623,000
10/01/2012
10/01/2042
10/01/2012
10/01/2042
350,000,000
13,300,000
7
114, 4.600%
350,000,000
4,224,661
791,000
08/19/2013
08/15/2043
08/19/2013
08/15/2043
350,000,000
16,100,000
8
116, 4.700%
350,000,000
3,670,733
115,500
01/10/2014
01/15/2044
01/10/2014
01/15/2044
350,000,000
16,450,000
9
117, 3.100%
250,000,000
2,675,378
212,500
11/10/2014
11/01/2024
11/10/2014
11/01/2024
4,520,833
10
118, 3.700%
400,000,000
4,497,729
03/02/2015
03/01/2045
03/02/2015
03/01/2045
400,000,000
14,800,000
11
119, 4.350%
450,000,000
5,643,725
3,501,000
11/19/2015
11/15/2045
11/19/2015
11/15/2045
450,000,000
19,575,000
12
120, 2.550%
500,000,000
4,325,512
06/27/2016
06/15/2026
06/27/2016
06/15/2026
500,000,000
12,750,000
13
121, 3.650%
700,000,000
7,630,653
4,543,000
06/27/2016
06/15/2046
06/27/2016
06/15/2046
700,000,000
25,550,000
14
122, 2.950%
350,000,000
3,084,480
959,000
08/23/2017
08/15/2027
08/23/2017
08/15/2027
350,000,000
10,325,000
15
123, 3.750%
650,000,000
7,187,392
1,625,000
08/23/2017
08/15/2047
08/23/2017
08/15/2047
650,000,000
24,375,000
16
124, 4.000%
800,000,000
8,806,005
152,000
02/20/2018
03/01/2048
02/20/2018
03/01/2048
800,000,000
32,000,000
17
125, 3.700%
550,000,000
5,724,371
1,320,000
08/14/2018
08/15/2028
08/14/2018
08/15/2028
550,000,000
20,350,000
18
126, 4.000%
400,000,000
5,320,038
3,256,000
02/19/2019
03/01/2049
02/19/2019
03/01/2049
400,000,000
16,000,000
19
127, 3.200%
300,000,000
3,958,928
2,349,000
11/12/2019
11/15/2049
11/12/2019
11/15/2049
300,000,000
9,600,000
20
128, 2.200%
350,000,000
3,831,604
1,064,000
02/18/2020
03/01/2030
02/18/2020
03/01/2030
350,000,000
7,700,000
21
129, 3.000%
650,000,000
8,523,636
897,000
02/18/2020
03/01/2050
02/18/2020
03/01/2050
650,000,000
19,500,000
22
130, 3.125%
700,000,000
9,221,373
952,000
03/09/2021
03/15/2051
03/09/2021
03/15/2051
700,000,000
21,875,000
23
131, 2.750%
450,000,000
4,695,716
94,500
08/12/2021
09/01/2051
08/12/2021
09/01/2051
450,000,000
12,375,000
24
132, 3.150%
300,000,000
3,265,761
384,000
03/15/2022
03/15/2032
03/15/2022
03/15/2032
300,000,000
9,450,000
25
133, 3.850%
450,000,000
5,905,442
796,500
03/15/2022
03/15/2052
03/15/2022
03/15/2052
450,000,000
17,325,000
26
134, 4.900%
400,000,000
4,419,289
1,336,000
01/10/2023
02/01/2033
01/10/2023
02/01/2033
400,000,000
19,600,000
27
135, 5.300%
575,000,000
7,643,212
1,397,250
01/10/2023
02/01/2053
01/10/2023
02/01/2053
575,000,000
30,475,000
28
136, 5.300%
400,000,000
4,042,973
1,432,000
05/13/2024
06/01/2034
05/13/2024
06/01/2034
400,000,000
13,426,667
29
137, 5.650%
400,000,000
4,942,972
2,592,000
05/13/2024
06/01/2054
05/13/2024
06/01/2054
400,000,000
14,313,333
30
Subtotal
(a)
12,500,000,000
139,269,657
47,756,500
12,153,600,000
482,534,833
31
Reacquired Bonds (Account 222)
32
33
34
35
Subtotal
36
Advances from Associated Companies (Account 223)
37
Subordinated Deferrable Interest Debentures, 6.350%,
206,186,000
2,256,515
186,000
03/17/2003
03/15/2033
03/17/2003
03/15/2033
206,186,000
13,092,811
38
ComEd FInancing III
39
Subtotal
206,186,000
2,256,515
186,000
206,186,000
13,092,811
40
Other Long Term Debt (Account 224)
41
42
43
44
Subtotal
33 TOTAL
12,706,186,000
12,359,786,000
(b)
495,627,644


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: BondsPrincipalAmountIssued
Changes in Account 221 during the year:
Issuances Retirements
First Mortgage Bonds $ 800,000,000  $ 250,000,000 
The unamortized debt discount, premium or expense on reacquired debt are transferred to Account 189, Unamortized Loss on Reacquired Debt, or Account 257, Unamortized Gain on Reacquired Debt, as appropriate, and amortized to expense over the life of the new long-term debt issued to finance the debt redemption, and\or over the life of the original debt issuance if the debt is not refinanced.
(b) Concept: InterestExpenseOnLongTermDebtIssued
Total interest reported on Pages 256-257 $ 495,627,644 
Amortization of settled cash flow swaps - losses 519,508 
Total for Accounts 427 and 430 $ 496,147,152 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
  1. Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount.
  2. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members.
  3. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.
Particulars (Details)
(a)
Amount
(b)
1
Net Income for the Year (Page 117)
1,066,087,097
2
Reconciling Items for the Year
3
4
Taxable Income Not Reported on Books
5
6
7
8
9
Deductions Recorded on Books Not Deducted for Return
10
See footnote for details
(a)
113,228,456
14
Income Recorded on Books Not Included in Return
15
16
17
18
19
Deductions on Return Not Charged Against Book Income
20
See footnote for details
(b)
431,726,233
27
Federal Tax Net Income
747,589,320
28
Show Computation of Tax:
29
Federal Income Tax at 21%
156,993,757
30
See footnote for details
(c)
83,056,956
31
Total
73,936,801
32
Federal Income Tax Acct 409.10
70,930,906
33
Federal Income Tax Acct 409.20
3,005,895


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: DeductionsRecordedOnBooksNotDeductedForReturn
Net Income for the Year (Page 117) $ 1,066,087,097 
Federal Income Tax (3,495,448)
State Income Tax 116,723,904 
Pre-tax Book Income $ 1,179,315,553 
(b) Concept: DeductionsOnReturnNotChargedAgainstBookIncome
Increase (Decrease) in Taxable Income Resulting From:
Removal Costs $ (159,236,508)
Mixed Service Costs (13,673,262)
Repair Allowance - Unit of Property (440,754,759)
Bonus Depreciation — 
Depreciation 185,766,340 
CIAC 144,192,488 
AFUDC Equity (37,985,228)
AFUDC Debt (28,941,210)
Capitalized Interest 45,343,830 
Gain/Loss on Disposition of Property (31,696,349)
Other (Property) 57,260,985 
Regulatory Assets & Liabilities (93,063,451)
Pension/OPEB/SERP (75,685,883)
Accrued Liabilities 188,510 
Merger Commitment Deferrals — 
State Income Taxes Deductible (64,324,889)
Deferred Revenue (1,022,306)
Fines & Penalties — 
Other (Net) 81,905,459 
Total Schedule M's $ (431,726,233)
(c) Concept: ComputationOfTax
Federal Taxable Income $ 747,589,320 
Computation of Federal Income Tax:
Federal Income Tax on Current Year Income (21%) $ 156,993,757 
Current Corporate Minimum Tax (72,525,518)
Income Tax Credits Utilized (9,315,291)
Net Operating Loss Utilized — 
Return to Accrual (3,079,205)
Uncertain Tax Positions 1,863,058 
2016-2021 R&D Affirmative — 
Federal Income Tax $ 73,936,801 
Federal Income Tax Account 409.10 $ 70,930,906 
Federal Income Tax Account 409.20 3,005,895 
Total $ 73,936,801 
Additional information in response to Instruction 2, Page 261:
The Respondent is a wholly-owned subsidiary of Exelon Corporation. The Respondent files a consolidated tax return with Exelon Corporation and Exelon Corporation's other subsidiaries. The consolidated federal income tax liability was allocated to the Respondent on a separate-return basis.

Corporate Alternative Minimum Tax Adjustment: This adjustment represents the difference between regular tax calculated at 21% of taxable income to the Corporate Alternative Minimum Tax calculated at 15% of Adjusted Financial Statement Income.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
  1. Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts.
  2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes.
  3. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts.
  4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
  5. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d).
  6. Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses.
  7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority.
  8. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts.
  9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
BALANCE AT BEGINNING OF YEAR BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED
Line No.
DescriptionOfTaxesAccruedPrepaidAndCharged
Kind of Tax (See Instruction 5)
(a)
TypeOfTax
Type of Tax
(b)
TaxJurisdiction
State
(c)
TaxYear
Tax Year
(d)
TaxesAccrued
Taxes Accrued (Account 236)
(e)
PrepaidTaxes
Prepaid Taxes (Include in Account 165)
(f)
TaxesCharged
Taxes Charged During Year
(g)
TaxesPaid
Taxes Paid During Year
(h)
TaxAdjustments
Adjustments
(i)
TaxesAccrued
Taxes Accrued (Account 236)
(j)
PrepaidTaxes
Prepaid Taxes (Included in Account 165)
(k)
TaxesAccruedPrepaidAndCharged
Electric (Account 408.1, 409.1)
(l)
IncomeTaxesExtraordinaryItems
Extraordinary Items (Account 409.3)
(m)
AdjustmentsToRetainedEarnings
Adjustment to Ret. Earnings (Account 439)
(n)
TaxesIncurredOther
Other
(o)
1
Renewable Energy Tax
Other Taxes
IL
(a)
2024
682,521
0
4,617,145
4,614,638
685,028
4,617,145
2
Low Income Tax
Other Taxes
IL
(b)
2024
6,011,255
0
37,344,477
37,858,790
5,496,942
43,425,533
6,081,056
3
Energy Transition Assistance Charge
Other Taxes
IL
(c)
2024
7,753,418
0
60,591,136
59,083,264
9,261,290
60,591,136
4
Electricity Distribution Tax
Other Taxes
IL
(d)
2024
0
(p)
13,598,581
105,532,637
99,549,000
(q)
8,966,815
1,351,871
105,532,637
5
Chicago Infrastructure Maintenance Fee
Other Taxes
IL
(e)
2024
10,707,308
0
85,011,767
85,085,230
10,633,845
85,011,767
6
Evanston Infrastructure Maintenance Fee
Other Taxes
IL
(f)
2024
58,531
0
495,443
486,037
67,937
495,443
7
Municipal Utility Tax
Other Taxes
IL
(g)
2024
29,000
0
1,583,517
1,499,558
112,959
1,205,579
377,938
8
Cook County Parking Tax
Other Taxes
IL
(h)
2024
4,863
0
70,901
71,651
4,113
225
71,126
9
Chicago Transaction Tax
Other Taxes
IL
(i)
2024
42,761
0
336,612
233,919
145,454
204,524
132,088
10
Public Utility Fund
Other Taxes
IL
(j)
2024
1,487,341
0
2,411,176
2,707,790
1,190,727
2,411,176
11
Joliet Motor Fuel Tax
Other Taxes
IL
(k)
2024
113,607
0
11,216
11,216
113,607
11,216
12
Subtotal Other Tax
26,890,605
13,598,581
298,006,027
291,201,093
8,966,815
29,063,773
303,505,931
5,499,904
13
Unemployment Insurance (SUTA)
Unemployment Tax
IL
2023
21,873
0
21,873
0
14
Unemployment Insurance (SUTA)
Unemployment Tax
IL
2024
0
0
1,208,609
1,199,556
9,053
550,884
657,725
15
Unemployment Insurance (FUTA)
Unemployment Tax
Fed
2023
6,425
0
6,425
0
16
Unemployment Insurance (FUTA)
Unemployment Tax
Fed
2024
0
0
299,214
297,034
2,180
137,431
161,783
17
Subtotal Unemployment Tax
28,298
0
1,507,823
1,524,888
11,233
688,315
819,508
18
Use Tax
Sales And Use Tax
IL
(l)
2024
3,273,352
0
11,670,081
13,364,294
1,579,139
38,497
11,631,584
19
Chicago Use Tax
Sales And Use Tax
IL
(m)
2024
504,664
0
687,484
899,498
292,650
2,990
684,494
20
Sales Tax
Sales And Use Tax
IL
2024
0
180,980
392,067
200,773
10,314
392,067
21
Subtotal Sales And Use Tax
3,778,016
180,980
12,749,632
14,464,565
1,882,103
41,487
12,708,145
22
Federal Income Tax
Income Tax
Fed
(n)
2024
110,580,596
0
73,934,863
186,601,832
(r)
2,086,373
0
70,955,520
2,979,343
23
State Income Tax
Income Tax
IL
(o)
2024
21,045,827
0
59,328,226
62,244,847
(s)
1,059,032
17,070,174
61,713,309
2,385,083
24
Subtotal Income Tax
131,626,423
0
133,263,089
248,846,679
1,027,341
17,070,174
132,668,829
594,260
25
Federal Excise Tax - Heavy Highway
Excise Tax
Fed
2024
0
0
13,510
13,510
0
7,460
6,050
26
Subtotal Excise Tax
0
0
13,510
13,510
0
7,460
6,050
27
Franchise
Franchise Tax
IL
2023
0
1,529,997
1,529,997
1,529,997
28
Franchise
Franchise Tax
IL
2024
0
0
1,268,497
2,536,993
1,268,496
1,268,497
29
Subtotal Franchise Tax
0
1,529,997
2,798,494
2,536,993
0
1,268,496
2,798,494
30
Real Estate
Property Tax
IL
2023
36,255,000
0
3,825,527
32,429,473
0
3,825,527
31
Real Estate
Property Tax
IL
2024
0
0
35,161,953
35,161,953
34,841,458
320,495
32
Subtotal Other Property Tax
36,255,000
0
31,336,426
32,429,473
35,161,953
31,015,931
320,495
33
Vehicle License
Other License And Fees Tax
IL
2023
0
677,718
677,718
0
677,718
34
Vehicle License
Other License And Fees Tax
IL
2024
0
0
1,298,004
2,005,062
0
707,058
1,298,004
35
Vehicle License-Local
Other License And Fees Tax
IL
2023
0
67,027
67,027
0
67,027
36
Vehicle License-Local
Other License And Fees Tax
IL
2024
0
0
128,374
198,303
0
69,929
128,374
37
Subtotal Other License And Fees Tax
0
744,745
2,171,123
2,203,365
0
776,987
2,171,123
38
Insurance Contributions (FICA)
Payroll Tax
Fed
2023
12,713,580
0
12,713,580
0
39
Insurance Contributions (FICA)
Payroll Tax
Fed
2024
0
0
74,511,164
62,476,821
12,034,343
34,086,862
40,424,302
40
Subtotal Payroll Tax
12,713,580
0
74,511,164
75,190,401
12,034,343
34,086,862
40,424,302
40
TOTAL
211,291,922
16,054,303
556,357,288
668,410,967
9,994,156
95,223,579
2,045,483
504,813,309
51,543,979


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: TaxYear
The tax year for Renewable Energy Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(b) Concept: TaxYear
The tax year for Low Income Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(c) Concept: TaxYear
The tax year for Energy Transition Assistance Charge Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(d) Concept: TaxYear
The tax year for Electricity Distribution Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(e) Concept: TaxYear
The tax year for Chicago Infrastructure Maintenance Fee Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(f) Concept: TaxYear
The tax year for Evanston Infrastructure Maintenance Fee Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(g) Concept: TaxYear
The tax year for Municipal Utility Taxes accrued, prepaid, and charged during year also applies to 2023 and prior years.
(h) Concept: TaxYear
The tax year for Cook County Parking Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(i) Concept: TaxYear
The tax year for Chicago Transaction Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(j) Concept: TaxYear
The tax year for Public Utility Fund Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(k) Concept: TaxYear
The tax year for Joliet Motor Fuel Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(l) Concept: TaxYear
The tax year for Use Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(m) Concept: TaxYear
The tax year for Chicago Use Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(n) Concept: TaxYear
The tax year for Federal Income Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(o) Concept: TaxYear
The tax year for Illinois Income Taxes accrued, prepaid, and charged during year also applies to the year 2023.
(p) Concept: PrepaidTaxes
$4,061,217 recorded in Account 186 and $9,537,364 recorded in Account 143.
(q) Concept: TaxAdjustments
Reclass to FERC Account 186 $ 8,966,815 
(r) Concept: TaxAdjustments
Reclass to FERC Account 143 $ 2,086,373 
(s) Concept: TaxAdjustments
Reclass from FERC Account 283 $ (1,059,032)

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)

Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.

Deferred for Year Allocations to Current Year's Income
Line No.
Account Subdivisions
(a)
Balance at Beginning of Year
(b)
Account No.
(c)
Amount
(d)
Account No.
(e)
Amount
(f)
Adjustments
(g)
Balance at End of Year
(h)
Average Period of Allocation to Income
(i)
ADJUSTMENT EXPLANATION
(j)
1
Electric Utility
2
3%
3
4%
47,244
2,615
49,859
45
4
7%
5
10%
4,814,080
936,383
3,877,697
32
6
Illinois ITC
1,948,977
461,119
59,526
2,350,570
41
8
TOTAL Electric (Enter Total of lines 2 thru 7)
6,810,301
461,119
993,294
6,278,126
9
Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10
`
47 OTHER TOTAL
48 GRAND TOTAL
6,810,301
461,119
993,294
6,278,126


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
OTHER DEFERRED CREDITS (Account 253)
  1. Report below the particulars (details) called for concerning other deferred credits.
  2. For any deferred credit being amortized, show the period of amortization.
  3. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
DEBITS
Line No.
Description and Other Deferred Credits
(a)
Balance at Beginning of Year
(b)
Contra Account
(c)
Amount
(d)
Credits
(e)
Balance at End of Year
(f)
1
(a)
Initial payments - contracts
3,940,593
3,940,593
2
(b)
Deferred rents
2,796
2,796
3
Long-term contracting services
633,644
633,644
4
Long-term renewable energy contracts
106,257,640
65,007,343
61,329,106
102,579,403
5
Funds for Utility Job Training Program (FEJA)
10,000,000
10,000,000
6
Other
574,536
37,324,956
36,926,622
972,870
47
TOTAL
120,260,137
102,335,095
98,255,728
116,180,770


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfOtherDeferredCredits
This item includes two contracts, with amortization periods starting April 1, 2000, and May 1, 2000, and continuing through March 31, 2030, and April 30, 2030, respectively.
(b) Concept: DescriptionOfOtherDeferredCredits
This item includes rents for various buildings, with amortization periods ranging from January 1, 1993 to December 31, 2023.
(c) Concept: DecreaseInOtherDeferredCreditsContraAccount
Other deferred credits are offset in Accounts 242, 454, 531, and 923.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report


End of:
2024
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1
Accelerated Amortization (Account 281)
2
Electric
3
Defense Facilities
4
Pollution Control Facilities
5
Other
5.1
Other (provide details in footnote):
8
TOTAL Electric (Enter Total of lines 3 thru 7)
9
Gas
10
Defense Facilities
11
Pollution Control Facilities
12
Other
12.1
Other (provide details in footnote):
15
TOTAL Gas (Enter Total of lines 10 thru 14)
16
Other
16.1
Other
16.2
Other
17
TOTAL (Acct 281) (Total of 8, 15 and 16)
18
Classification of TOTAL
19
Federal Income Tax
20
State Income Tax
21
Local Income Tax


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
  1. Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1 Account 282
2
Electric
4,971,124,063
184,170,242
322,898,753
254, 410, 411
4,982,461
254, 410, 411
213,881,637
5,041,294,728
3
Gas
4
Other (Specify)
5
Total (Total of lines 2 thru 4)
4,971,124,063
184,170,242
322,898,753
4,982,461
213,881,637
(a)
5,041,294,728
6
7
8
9
TOTAL Account 282 (Total of Lines 5 thru 8)
4,971,124,063
184,170,242
322,898,753
4,982,461
213,881,637
5,041,294,728
10
Classification of TOTAL
11
Federal Income Tax
3,410,008,455
106,092,060
286,186,005
213,881,637
3,443,796,147
12
State Income Tax
1,561,115,608
78,078,182
36,712,748
4,982,461
1,597,498,581
13
Local Income Tax


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxesOtherProperty
Description: Beginning Balance Ending Balance
AFUDC Equity $ 63,954,946  $ 72,580,462 
CIAC (156,724,498) (178,692,699)
Plant Deferred Taxes - FAS 109 5,063,893,615  5,147,406,965 
Total $ 4,971,124,063  $ 5,041,294,728 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
  1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283.
  2. For other (Specify),include deferrals relating to other income and deductions.
  3. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other.
  4. Use footnotes as required.
CHANGES DURING YEAR ADJUSTMENTS
Debits Credits
Line No.
Account
(a)
Balance at Beginning of Year
(b)
Amounts Debited to Account 410.1
(c)
Amounts Credited to Account 411.1
(d)
Amounts Debited to Account 410.2
(e)
Amounts Credited to Account 411.2
(f)
Account Credited
(g)
Amount
(h)
Account Debited
(i)
Amount
(j)
Balance at End of Year
(k)
1 Account 283
2
Electric
3
1,346,374,129
192,681,241
126,952,710
3,676,408
1,415,779,068
9 TOTAL Electric (Total of lines 3 thru 8)
1,346,374,129
192,681,241
126,952,710
3,676,408
1,415,779,068
10
Gas
11
12
13
14
15
16
17 TOTAL Gas (Total of lines 11 thru 16)
18 TOTAL Other
19 TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)
1,346,374,129
192,681,241
126,952,710
3,676,408
(a)
1,415,779,068
20
Classification of TOTAL
21
Federal Income Tax
897,661,489
128,447,140
84,624,276
190, 236, 254
2,451,153
943,935,506
22
State Income Tax
448,712,640
64,234,101
42,328,434
190, 236, 254
1,225,255
471,843,562
23
Local Income Tax
NOTES


FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxesOther
Description Beginning Balance Ending Balance
Pension Asset $ 347,053,474  $ 385,308,540 
Regulatory Asset 969,087,038  992,037,219 
Unamortized Loss on Required Debt 4,681,661  4,230,035 
Other 25,551,956  34,203,274 
Total $ 1,346,374,129  $ 1,415,779,068 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
OTHER REGULATORY LIABILITIES (Account 254)
  1. Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable.
  2. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes.
  3. For Regulatory Liabilities being amortized, show period of amortization.
DEBITS
Line No.
Description and Purpose of Other Regulatory Liabilities
(a)
Balance at Beginning of Current Quarter/Year
(b)
Account Credited
(c)
Amount
(d)
Credits
(e)
Balance at End of Current Quarter/Year
(f)
1
(a)
Decommissioning the Regulatory Agreement Units
2,954,412,181
825,254,983
3,779,667,164
2
Purchased Electricity - Over Recovery
73,252
88,505,990
100,261,131
11,828,393
3
Deferred Income Taxes
2,177,670,710
293,012,692
6,593,399
1,891,251,417
4
Transmission Costs - Over Recovery
14,000,739
50,000,002
35,999,263
5
Renewable Portfolio Standard Costs - Rider REA
1,033,110,493
263,109,920
1,296,220,413
6
Renewable Portfolio Standard Costs - ACP Funds
69,057,169
3,796,928
72,854,097
7
Purchased Electricity - FERC 494 Refund
4,306,304
4,804,274
497,970
8
Coal to Solar
912,324
10,016
922,340
41 TOTAL
6,253,543,172
436,322,958
1,235,523,610
7,052,743,824


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities
Line Item Rate Order Docket Number Or Recovery Mechanism Amortization Period
Decommissioning the Regulatory Agreement Units ICC Docket 00-0361 N/A
Purchased Electricity - Over Recovery ICC Docket No. 05-0159 & 18-1824 4 months from period end
Deferred Income Taxes ICC Order 18-0034 / FERC Order ER19-5 dated 4/26/2019 Over the life of related assets
Transmission Costs - Over Recovery FERC Docket ER07-583 12 months from each June
Renewable Portfolio Standard Costs - Rider REA FEJA 9 months from each September
Renewable Portfolio Standard Costs - ACP Funds IPA LTRRP approved by ICC As approved by the IPA & ICC
Purchased Electricity - FERC 494 Refund FERC Order Docket No. EL05-121-009 Amortization complete as of 12/31/2024 based on settlement amounts which were processed through PJM
Coal to Solar CEJA 12 months from each October

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
Electric Operating Revenues
  1. The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages.
  2. Report below operating revenues for each prescribed account, and manufactured gas revenues in total.
  3. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month.
  4. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote.
  5. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2.
  6. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.)
  7. See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases.
  8. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts.
  9. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.
Title of Account
(a)
Operating Revenues Year to Date Quarterly/Annual
(b)
Operating Revenues Previous year (no Quarterly)
(c)
MEGAWATT HOURS SOLD Year to Date Quarterly/Annual
(d)
MEGAWATT HOURS SOLD Amount Previous year (no Quarterly)
(e)
AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly)
(f)
AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly)
(g)
1
SalesOfElectricityHeadingAbstract
Sales of Electricity
2
ResidentialSalesAbstract
(440) Residential Sales
3,734,733,091
3,862,275,761
27,273,825
26,022,565
3,727,675
3,732,459
3
CommercialAndIndustrialSalesAbstract
(442) Commercial and Industrial Sales
4
CommercialSalesAbstract
Small (or Comm.) (See Instr. 4)
2,217,249,637
2,027,198,786
28,366,580
28,705,593
395,314
391,406
5
IndustrialSalesAbstract
Large (or Ind.) (See Instr. 4)
1,107,159,699
896,098,046
27,869,630
26,707,834
2,051
1,875
6
PublicStreetAndHighwayLightingAbstract
(444) Public Street and Highway Lighting
43,735,834
45,348,653
444,828
454,308
5,707
4,796
7
OtherSalesToPublicAuthoritiesAbstract
(445) Other Sales to Public Authorities
8
SalesToRailroadsAndRailwaysAbstract
(446) Sales to Railroads and Railways
14,504,101
12,241,981
376,332
399,921
2
2
9
InterdepartmentalSalesAbstract
(448) Interdepartmental Sales
10
SalesToUltimateConsumersAbstract
TOTAL Sales to Ultimate Consumers
7,117,382,362
6,843,163,227
(f)(g)
84,331,195
(h)
82,290,221
4,130,749
4,130,538
11
SalesForResaleAbstract
(447) Sales for Resale
20,927,736
27,394,838
791,465
988,910
12
SalesOfElectricityAbstract
TOTAL Sales of Electricity
7,138,310,098
6,870,558,065
85,122,660
83,279,131
4,130,749
4,130,538
13
ProvisionForRateRefundsAbstract
(Less) (449.1) Provision for Rate Refunds
14
RevenuesNetOfProvisionForRefundsAbstract
TOTAL Revenues Before Prov. for Refunds
7,138,310,098
6,870,558,065
85,122,660
83,279,131
4,130,749
4,130,538
15
OtherOperatingRevenuesAbstract
Other Operating Revenues
16
ForfeitedDiscounts
(450) Forfeited Discounts
14,347,873
28,067,219
17
MiscellaneousServiceRevenues
(451) Miscellaneous Service Revenues
(a)
19,000,296
(d)
19,161,315
18
SalesOfWaterAndWaterPower
(453) Sales of Water and Water Power
19
RentFromElectricProperty
(454) Rent from Electric Property
95,390,314
87,133,133
20
InterdepartmentalRents
(455) Interdepartmental Rents
21
OtherElectricRevenue
(456) Other Electric Revenues
(b)
12,770,917
(e)
10,583,695
22
RevenuesFromTransmissionOfElectricityOfOthers
(456.1) Revenues from Transmission of Electricity of Others
909,707,286
831,947,358
23
RegionalTransmissionServiceRevenues
(457.1) Regional Control Service Revenues
24
MiscellaneousRevenue
(457.2) Miscellaneous Revenues
25
OtherMiscellaneousOperatingRevenues
Other Miscellaneous Operating Revenues
26
OtherOperatingRevenues
TOTAL Other Operating Revenues
1,025,674,852
976,892,720
27
ElectricOperatingRevenues
TOTAL Electric Operating Revenues
(c)
8,163,984,950
7,847,450,785
Line12, column (b) includes $
451,537,510
of unbilled revenues.
Line12, column (d) includes
220,388
MWH relating to unbilled revenues


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: MiscellaneousServiceRevenues
Account 451 (Miscellaneous Service Revenues) details are required by Page 300, Instruction No. 5
For the Years Ended December 31,
2024 2023
Meter Tampering $ 41,247  $ 250,454 
Temporary Service Revenues 2,787,669  3,905,485 
Electric Choice & Other Data Service Fees 1,772  27,612 
Turn On Charge 351,422  994,596 
Returned Check Fees 1,400,790  1,390,351 
Call Center Referral Services (83,550) 114,569 
Deferred Payment Agreement Reinstatement Fees 1,343,896  2,540,168 
Energy Marketplace Services 120,210  209,095 
Interconnection Application & Facility Study Fees 10,976,359  8,514,928 
AMI Metering Opt-out Fees 995,443  1,061,222 
Other 1,065,038  152,835 
Total $ 19,000,296  $ 19,161,315 
(b) Concept: OtherElectricRevenue
Account 456 (Other Electric Revenues) details are required by Page 300, Instruction No. 5
For the Years Ended December 31,
2024 2023
Contracting & Engineering Study Services $ 1,067,073  $ 9,794,273 
IPP Electric Generation Studies reimbursements 6,546,931  517,586 
Beneficial Electrification Incentives (21,253,203) (654,750)
Affiliate meter and other equipment rentals 15,909  12,611 
Affiliate maintenance revenues 852,373  913,975 
Total
$ (12,770,917) $ 10,583,695 
(c) Concept: ElectricOperatingRevenues
Total Electric Operating Revenues include the following amounts included in ComEd's 2024 revenue balancing reconciliation:
Total Delivery Service Operating Revenue $ 3,496,179,688 
Total Electric Operating Revenues include the following amounts included in ComEd's 2024 energy efficiency formula rate reconciliation:
Total Energy Efficiency Operating Revenue
$ 368,080,000 
2024 Estimated Reconciliation Recorded as of December 31, 2024
19,064,000 
*
* Amount included in Total Energy Efficiency Operating Revenue reported above
Total Electric Operating Revenues include the following amounts included in ComEd's 2024 distributed generation rebate formula rate reconciliation:
Total Distributed Generation Rebate Operating Revenue
$ 22,985,000 
2024 Estimated Reconciliation Recorded as of December 31, 2024
3,196,000 
*
* Amount included in Total Distributed Generation Rebate Operating Revenue reported above
(d) Concept: MiscellaneousServiceRevenues
Refer to the footnote for Line No. 17, column b.
(e) Concept: OtherElectricRevenue
Refer to the footnote for Line No. 21, column b.
(f) Concept: MegawattHoursSoldSalesToUltimateConsumers
MWh's for the Years Ended December 31,
2024 2023
Retail deliveries for Full Service
$ 30,116,920  $ 29,964,172 
Retail deliveries for Delivery Only
54,214,275 52,326,049
Total retail deliveries
$ 84,331,195  $ 82,290,221 
General Notes:
Full Service reflects deliveries to customers taking electric service under tariff rates. Delivery Only service reflects customers electing to receive electricity from Alternative Retail Electric Suppliers.
(g) Concept: MegawattHoursSoldSalesToUltimateConsumers
Retail deliveries for Full Service $ 30,116,920 
Retail deliveries for Delivery Only 54,214,275 
Total Sales to Ultimate Customers $ 84,331,195 
Refer to the footnote on Page 300, line No. 10, Column (d) for additional details.
(h) Concept: MegawattHoursSoldSalesToUltimateConsumers
Refer to the footnote for Line No. 10, column d.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
  1. The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.
Description of Service
(a)
Balance at End of Quarter 1
(b)
Balance at End of Quarter 2
(c)
Balance at End of Quarter 3
(d)
Balance at End of Year
(e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
TOTAL


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
(a)
BES - Residential
19,260,037
3,061,021,577
2,879,773
6,688
0.1589
2
BES - Residential Space Heating
1,202,387
185,040,605
43,562
27,602
0.1539
3
BES H - Hourly
419,707
58,614,659
975
430,469
0.1397
4
(b)
BES - Outdoor Lighting
4,941
1,049,836
2,016
2,451
0.2125
5
RDS - Delivery Service
6,406,826
604,054,430
805,381
7,955
0.0943
41 TOTAL Billed Residential Sales
27,293,898
3,909,781,107
3,727,675
7,322
0.1432
42 TOTAL Unbilled Rev. (See Instr. 6)
20,073
175,048,016
8.7206
43 TOTAL
27,273,825
3,734,733,091
3,727,675
7,317
0.1369


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: DescriptionOfNumberAndTitleOfRateSchedule
The following legend is applicable for the various rates shown in column (a) -
BES is Basic Electric Service
RDS is Retail Delivery Service
(b) Concept: DescriptionOfNumberAndTitleOfRateSchedule
Each class of customers may have multiple billing rates, a primary rate, and for certain customers, an Outdoor Lighting rate. In order to appropriately calculate the amount presented in Column (e) on Page 304, these customers are reported in each class separately for Page 304. However, for purposes of page 300-301, Column (f), the customers are reported only once. This footnote applies to all BES - Outdoor Lighting lines shown in Column (a).

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
BES - Fixed
4,628,899
706,542,407
220,014
21,039
0.1526
2
BES H - Hourly
3,314,505
344,890,014
8,501
389,896
0.1041
3
BES - Outdoor Lighting
23,012
3,087,128
525
43,832
0.1342
4
RDS - Delivery Service
20,468,387
1,309,704,348
166,274
123,100
0.0640
41 TOTAL Billed Small or Commercial
28,434,803
2,364,223,897
395,314
71,930
0.0831
42 TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)
68,223
146,974,260
2.1543
43 TOTAL Small or Commercial
28,366,580
2,217,249,637
395,314
71,757
0.0782


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
BES - Fixed
8,643
891,355
15
576,200
0.1031
2
BES H - Hourly
1,634,293
127,544,044
161
10,150,888
0.0780
3
BES - Outdoor Lighting
162
5,457
94
1,723
0.0337
4
RDS - Delivery Service
25,870,368
1,101,947,948
1,781
14,525,754
0.0426
41 TOTAL Billed Large (or Ind.) Sales
27,513,466
1,230,377,890
2,051
13,414,659
0.0447
42 TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)
356,164
123,218,191
0.3460
43 TOTAL Large (or Ind.)
27,869,630
1,107,159,699
2,051
13,588,313
0.0397


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
BES H - Hourly
70,895
12,401,889
926
76,560
0.1749
2
BES - Outdoor Lighting
40,255
8,931,286
3,231
12,459
0.2219
3
RDS - Delivery Service
334,631
25,075,194
1,550
215,891
0.0749
41 TOTAL Billed Public Street and Highway Lighting
445,781
46,408,369
5,707
78,111
0.1041
42 TOTAL Unbilled Rev. (See Instr. 6)
953
2,672,535
2.8043
43 TOTAL
444,828
43,735,834
5,707
77,944
0.0983


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
1
RDS - railroads
422,859
18,128,609
2
211,429,500
0.0429
41 TOTAL Billed Sales To Railroads and Railways
422,859
18,128,609
2
211,429,500
0.0429
42 TOTAL Unbilled Rev. (See Instr. 6)
46,527
3,624,508
0.0779
43 TOTAL
376,332
14,504,101
2
188,166,000
0.0385


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
SALES OF ELECTRICITY BY RATE SCHEDULES
  1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310.
  2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading.
  3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.
  4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly).
  5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto.
  6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.
Number and Title of Rate Schedule
(a)
MWh Sold
(b)
Revenue
(c)
Average Number of Customers
(d)
KWh of Sales Per Customer
(e)
Revenue Per KWh Sold
(f)
41 TOTAL Billed - All Accounts
84,110,807
7,568,919,872
4,130,749
20,362
0.0900
42 TOTAL Unbilled Rev. (See Instr. 6) - All Accounts
220,388
451,537,510
2.0488
43 TOTAL - All Accounts
(a)
84,331,195
7,117,382,362
4,130,749
20,415
0.0844


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: MegawattHoursOfElectricitySoldByRateSchedulesIncludingUnbilledRevenue
MWh's for the Years Ended December 31,
2024 2023
Retail Deliveries for Full Service 30,116,920  29,964,172 
Retail Deliveries for Delivery Only 54,214,275  52,326,049 
   Total Retail Deliveries 84,331,195  82,290,221 
General Notes:
Full Service reflects deliveries to customers taking electric service under tariff rates. Delivery Only service reflects customers electing to receive electricity from a competitive electric generation supplier.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
SALES FOR RESALE (Account 447)
  1. Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326).
  2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser.
  3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:

    RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers.

    LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract.

    IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years.

    SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less.

    LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit.

    IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years.

    OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote.

    AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment.

  4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k).
  5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided.
  6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.
  7. Report in column (g) the megawatt hours shown on bills rendered to the purchaser.
  8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser.
  9. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24.
  10. Footnote entries as required and provide explanations following all required data.
ACTUAL DEMAND (MW) REVENUE
Line No.
Name of Company or Public Authority (Footnote Affiliations)
(a)
Statistical Classification
(b)
FERC Rate Schedule or Tariff Number
(c)
Average Monthly Billing Demand (MW)
(d)
Average Monthly NCP Demand
(e)
Average Monthly CP Demand
(f)
Megawatt Hours Sold
(g)
Demand Charges ($)
(h)
Energy Charges ($)
(i)
Other Charges ($)
(j)
Total ($) (h+i+j)
(k)
1
Requirement Sales:
2
Non-Requirement Sales:
3
(a)
PJM Interconnection, LLC
791,465
20,927,736
20,927,736
15
Subtotal - RQ
16
Subtotal-Non-RQ
791,465
20,927,736
20,927,736
17 Total
791,465
20,927,736
20,927,736


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityReceivingElectricityPurchasedForResale
The MegaWatt Hours Sold and the associated Revenue Energy Charges reflect spot market sales.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
ELECTRIC OPERATION AND MAINTENANCE EXPENSES

If the amount for previous year is not derived from previously reported figures, explain in footnote.

Line No.
Account
(a)
Amount for Current Year
(b)
Amount for Previous Year (c)
(c)
1
PowerProductionExpensesAbstract
1. POWER PRODUCTION EXPENSES
2
SteamPowerGenerationAbstract
A. Steam Power Generation
3
SteamPowerGenerationOperationAbstract
Operation
4
OperationSupervisionAndEngineeringSteamPowerGeneration
(500) Operation Supervision and Engineering
5
FuelSteamPowerGeneration
(501) Fuel
6
SteamExpensesSteamPowerGeneration
(502) Steam Expenses
7
SteamFromOtherSources
(503) Steam from Other Sources
8
SteamTransferredCredit
(Less) (504) Steam Transferred-Cr.
9
ElectricExpensesSteamPowerGeneration
(505) Electric Expenses
10
MiscellaneousSteamPowerExpenses
(506) Miscellaneous Steam Power Expenses
11
RentsSteamPowerGeneration
(507) Rents
12
Allowances
(509) Allowances
13
SteamPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 4 thru 12)
14
SteamPowerGenerationMaintenanceAbstract
Maintenance
15
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
(510) Maintenance Supervision and Engineering
16
MaintenanceOfStructuresSteamPowerGeneration
(511) Maintenance of Structures
17
MaintenanceOfBoilerPlantSteamPowerGeneration
(512) Maintenance of Boiler Plant
18
MaintenanceOfElectricPlantSteamPowerGeneration
(513) Maintenance of Electric Plant
19
MaintenanceOfMiscellaneousSteamPlant
(514) Maintenance of Miscellaneous Steam Plant
20
SteamPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 15 thru 19)
21
PowerProductionExpensesSteamPower
TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)
22
NuclearPowerGenerationAbstract
B. Nuclear Power Generation
23
NuclearPowerGenerationOperationAbstract
Operation
24
OperationSupervisionAndEngineeringNuclearPowerGeneration
(517) Operation Supervision and Engineering
25
NuclearFuelExpense
(518) Fuel
26
CoolantsAndWater
(519) Coolants and Water
27
SteamExpensesNuclearPowerGeneration
(520) Steam Expenses
28
SteamFromOtherSourcesNuclearPowerGeneration
(521) Steam from Other Sources
29
SteamTransferredCreditNuclearPowerGeneration
(Less) (522) Steam Transferred-Cr.
30
ElectricExpensesNuclearPowerGeneration
(523) Electric Expenses
31
MiscellaneousNuclearPowerExpenses
(524) Miscellaneous Nuclear Power Expenses
32
RentsNuclearPowerGeneration
(525) Rents
33
NuclearPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of lines 24 thru 32)
34
NuclearPowerGenerationMaintenanceAbstract
Maintenance
35
MaintenanceSupervisionAndEngineeringNuclearPowerGeneration
(528) Maintenance Supervision and Engineering
36
MaintenanceOfStructuresNuclearPowerGeneration
(529) Maintenance of Structures
37
MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration
(530) Maintenance of Reactor Plant Equipment
38
MaintenanceOfElectricPlantNuclearPowerGeneration
(531) Maintenance of Electric Plant
39
MaintenanceOfMiscellaneousNuclearPlant
(532) Maintenance of Miscellaneous Nuclear Plant
40
NuclearPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 35 thru 39)
41
PowerProductionExpensesNuclearPower
TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)
42
HydraulicPowerGenerationAbstract
C. Hydraulic Power Generation
43
HydraulicPowerGenerationOperationAbstract
Operation
44
OperationSupervisionAndEngineeringHydraulicPowerGeneration
(535) Operation Supervision and Engineering
45
WaterForPower
(536) Water for Power
46
HydraulicExpenses
(537) Hydraulic Expenses
47
ElectricExpensesHydraulicPowerGeneration
(538) Electric Expenses
48
MiscellaneousHydraulicPowerGenerationExpenses
(539) Miscellaneous Hydraulic Power Generation Expenses
49
RentsHydraulicPowerGeneration
(540) Rents
50
HydraulicPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 44 thru 49)
51
HydraulicPowerGenerationContinuedAbstract
C. Hydraulic Power Generation (Continued)
52
HydraulicPowerGenerationMaintenanceAbstract
Maintenance
53
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
(541) Mainentance Supervision and Engineering
54
MaintenanceOfStructuresHydraulicPowerGeneration
(542) Maintenance of Structures
55
MaintenanceOfReservoirsDamsAndWaterways
(543) Maintenance of Reservoirs, Dams, and Waterways
56
MaintenanceOfElectricPlantHydraulicPowerGeneration
(544) Maintenance of Electric Plant
57
MaintenanceOfMiscellaneousHydraulicPlant
(545) Maintenance of Miscellaneous Hydraulic Plant
58
HydraulicPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of lines 53 thru 57)
59
PowerProductionExpensesHydraulicPower
TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
60
OtherPowerGenerationAbstract
D. Other Power Generation
61
OtherPowerGenerationOperationAbstract
Operation
62
OperationSupervisionAndEngineeringOtherPowerGeneration
(546) Operation Supervision and Engineering
63
Fuel
(547) Fuel
64
GenerationExpenses
(548) Generation Expenses
64.1
OperationOfEnergyStorageEquipment
(548.1) Operation of Energy Storage Equipment
65
MiscellaneousOtherPowerGenerationExpenses
(549) Miscellaneous Other Power Generation Expenses
66
RentsOtherPowerGeneration
(550) Rents
67
OtherPowerGenerationOperationsExpense
TOTAL Operation (Enter Total of Lines 62 thru 67)
68
OtherPowerGenerationMaintenanceAbstract
Maintenance
69
MaintenanceSupervisionAndEngineeringOtherPowerGeneration
(551) Maintenance Supervision and Engineering
70
MaintenanceOfStructures
(552) Maintenance of Structures
71
MaintenanceOfGeneratingAndElectricPlant
(553) Maintenance of Generating and Electric Plant
71.1
MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration
(553.1) Maintenance of Energy Storage Equipment
72
MaintenanceOfMiscellaneousOtherPowerGenerationPlant
(554) Maintenance of Miscellaneous Other Power Generation Plant
73
OtherPowerGenerationMaintenanceExpense
TOTAL Maintenance (Enter Total of Lines 69 thru 72)
74
PowerProductionExpensesOtherPower
TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)
75
OtherPowerSuplyExpensesAbstract
E. Other Power Supply Expenses
76
PurchasedPower
(555) Purchased Power
1,381,297,380
1,742,592,887
76.1
PowerPurchasedForStorageOperations
(555.1) Power Purchased for Storage Operations
77
SystemControlAndLoadDispatchingElectric
(556) System Control and Load Dispatching
78
OtherExpensesOtherPowerSupplyExpenses
(557) Other Expenses
1,259,660,722
701,205,113
79
OtherPowerSupplyExpense
TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)
2,640,958,102
2,443,798,000
80
PowerProductionExpenses
TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)
2,640,958,102
2,443,798,000
81
TransmissionExpensesAbstract
2. TRANSMISSION EXPENSES
82
TransmissionExpensesOperationAbstract
Operation
83
OperationSupervisionAndEngineeringElectricTransmissionExpenses
(560) Operation Supervision and Engineering
29,451,209
26,886,530
85
LoadDispatchReliability
(561.1) Load Dispatch-Reliability
86
LoadDispatchMonitorAndOperateTransmissionSystem
(561.2) Load Dispatch-Monitor and Operate Transmission System
87
LoadDispatchTransmissionServiceAndScheduling
(561.3) Load Dispatch-Transmission Service and Scheduling
88
SchedulingSystemControlAndDispatchServices
(561.4) Scheduling, System Control and Dispatch Services
415,402,822
397,423,917
89
ReliabilityPlanningAndStandardsDevelopment
(561.5) Reliability, Planning and Standards Development
90
TransmissionServiceStudies
(561.6) Transmission Service Studies
43,485
24,238
91
GenerationInterconnectionStudies
(561.7) Generation Interconnection Studies
4,200,898
357,679
92
ReliabilityPlanningAndStandardsDevelopmentServices
(561.8) Reliability, Planning and Standards Development Services
22,092,777
15,259,248
93
StationExpensesTransmissionExpense
(562) Station Expenses
3,671,290
2,597,339
93.1
OperationOfEnergyStorageEquipmentTransmissionExpense
(562.1) Operation of Energy Storage Equipment
94
OverheadLineExpense
(563) Overhead Lines Expenses
360,000
390,000
95
UndergroundLineExpensesTransmissionExpense
(564) Underground Lines Expenses
631,724
324,074
96
TransmissionOfElectricityByOthers
(565) Transmission of Electricity by Others
10,271,201
10,659,454
97
MiscellaneousTransmissionExpenses
(566) Miscellaneous Transmission Expenses
(a)
28,182,513
(c)
25,596,876
98
RentsTransmissionElectricExpense
(567) Rents
1,384,952
1,428,087
99
TransmissionOperationExpense
TOTAL Operation (Enter Total of Lines 83 thru 98)
514,972,871
480,167,442
100
TransmissionMaintenanceAbstract
Maintenance
101
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses
(568) Maintenance Supervision and Engineering
1,341,025
1,463,052
102
MaintenanceOfStructuresTransmissionExpense
(569) Maintenance of Structures
650,421
1,397,640
103
MaintenanceOfComputerHardwareTransmission
(569.1) Maintenance of Computer Hardware
524,678
299,080
104
MaintenanceOfComputerSoftwareTransmission
(569.2) Maintenance of Computer Software
2,843,886
1,804,347
105
MaintenanceOfCommunicationEquipmentElectricTransmission
(569.3) Maintenance of Communication Equipment
1,092,473
495,512
106
MaintenanceOfMiscellaneousRegionalTransmissionPlant
(569.4) Maintenance of Miscellaneous Regional Transmission Plant
107
MaintenanceOfStationEquipmentTransmission
(570) Maintenance of Station Equipment
32,320,746
24,010,672
107.1
MaintenanceOfEnergyStorageEquipmentTransmission
(570.1) Maintenance of Energy Storage Equipment
108
MaintenanceOfOverheadLinesTransmission
(571) Maintenance of Overhead Lines
28,160,597
25,958,394
109
MaintenanceOfUndergroundLinesTransmission
(572) Maintenance of Underground Lines
1,114,946
2,067,106
110
MaintenanceOfMiscellaneousTransmissionPlant
(573) Maintenance of Miscellaneous Transmission Plant
596,199
8,959,648
111
TransmissionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 101 thru 110)
66,415,079
66,455,451
112
TransmissionExpenses
TOTAL Transmission Expenses (Total of Lines 99 and 111)
581,387,950
546,622,893
113
RegionalMarketExpensesAbstract
3. REGIONAL MARKET EXPENSES
114
RegionalMarketExpensesOperationAbstract
Operation
115
OperationSupervision
(575.1) Operation Supervision
116
DayAheadAndRealTimeMarketAdministration
(575.2) Day-Ahead and Real-Time Market Facilitation
117
TransmissionRightsMarketAdministration
(575.3) Transmission Rights Market Facilitation
118
CapacityMarketAdministration
(575.4) Capacity Market Facilitation
119
AncillaryServicesMarketAdministration
(575.5) Ancillary Services Market Facilitation
120
MarketMonitoringAndCompliance
(575.6) Market Monitoring and Compliance
121
MarketFacilitationMonitoringAndComplianceServices
(575.7) Market Facilitation, Monitoring and Compliance Services
8,464,510
6,841,512
122
RentsRegionalMarketExpenses
(575.8) Rents
123
RegionalMarketOperationExpense
Total Operation (Lines 115 thru 122)
8,464,510
6,841,512
124
RegionalMarketExpensesMaintenanceAbstract
Maintenance
125
MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses
(576.1) Maintenance of Structures and Improvements
126
MaintenanceOfComputerHardware
(576.2) Maintenance of Computer Hardware
127
MaintenanceOfComputerSoftware
(576.3) Maintenance of Computer Software
128
MaintenanceOfCommunicationEquipmentRegionalMarketExpenses
(576.4) Maintenance of Communication Equipment
129
MaintenanceOfMiscellaneousMarketOperationPlant
(576.5) Maintenance of Miscellaneous Market Operation Plant
130
RegionalMarketMaintenanceExpense
Total Maintenance (Lines 125 thru 129)
131
RegionalMarketExpenses
TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)
8,464,510
6,841,512
132
DistributionExpensesAbstract
4. DISTRIBUTION EXPENSES
133
DistributionExpensesOperationAbstract
Operation
134
OperationSupervisionAndEngineeringDistributionExpense
(580) Operation Supervision and Engineering
21,599,243
26,273,230
135
LoadDispatching
(581) Load Dispatching
72,200
81,592
136
StationExpensesDistribution
(582) Station Expenses
1,769,922
1,367,288
137
OverheadLineExpenses
(583) Overhead Line Expenses
7,813,568
3,090,935
138
UndergroundLineExpenses
(584) Underground Line Expenses
22,845,719
20,013,201
138.1
OperationOfEnergyStorageEquipmentDistribution
(584.1) Operation of Energy Storage Equipment
139
StreetLightingAndSignalSystemExpenses
(585) Street Lighting and Signal System Expenses
3,337,620
2,328,703
140
MeterExpenses
(586) Meter Expenses
8,107,173
9,988,294
141
CustomerInstallationsExpenses
(587) Customer Installations Expenses
26,897,270
18,598,507
142
MiscellaneousDistributionExpenses
(588) Miscellaneous Expenses
123,860,210
106,833,329
143
RentsDistributionExpense
(589) Rents
5,284,113
4,283,656
144
DistributionOperationExpensesElectric
TOTAL Operation (Enter Total of Lines 134 thru 143)
221,587,038
192,858,735
145
DistributionExpensesMaintenanceAbstract
Maintenance
146
MaintenanceSupervisionAndEngineering
(590) Maintenance Supervision and Engineering
6,255,990
6,584,314
147
MaintenanceOfStructuresDistributionExpense
(591) Maintenance of Structures
2,282,694
2,043,511
148
MaintenanceOfStationEquipment
(592) Maintenance of Station Equipment
52,392,033
43,855,527
148.1
MaintenanceOfEnergyStorageEquipment
(592.2) Maintenance of Energy Storage Equipment
149
MaintenanceOfOverheadLines
(593) Maintenance of Overhead Lines
237,697,241
223,450,528
150
MaintenanceOfUndergroundLines
(594) Maintenance of Underground Lines
67,546,728
55,416,786
151
MaintenanceOfLineTransformers
(595) Maintenance of Line Transformers
6,093,218
6,818,851
152
MaintenanceOfStreetLightingAndSignalSystems
(596) Maintenance of Street Lighting and Signal Systems
2,211,780
2,433,605
153
MaintenanceOfMeters
(597) Maintenance of Meters
1,669,096
1,167,490
154
MaintenanceOfMiscellaneousDistributionPlant
(598) Maintenance of Miscellaneous Distribution Plant
10,421,514
9,962,073
155
DistributionMaintenanceExpenseElectric
TOTAL Maintenance (Total of Lines 146 thru 154)
383,232,102
351,732,685
156
DistributionExpenses
TOTAL Distribution Expenses (Total of Lines 144 and 155)
604,819,140
544,591,420
157
CustomerAccountsExpensesAbstract
5. CUSTOMER ACCOUNTS EXPENSES
158
CustomerAccountsExpensesOperationsAbstract
Operation
159
SupervisionCustomerAccountExpenses
(901) Supervision
276,146
336,289
160
MeterReadingExpenses
(902) Meter Reading Expenses
16,223,048
16,440,582
161
CustomerRecordsAndCollectionExpenses
(903) Customer Records and Collection Expenses
214,977,707
197,074,440
162
UncollectibleAccounts
(904) Uncollectible Accounts
70,648,877
44,780,156
163
MiscellaneousCustomerAccountsExpenses
(905) Miscellaneous Customer Accounts Expenses
164
CustomerAccountExpenses
TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)
302,125,778
258,631,467
165
CustomerServiceAndInformationalExpensesAbstract
6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166
CustomerServiceAndInformationalExpensesOperationAbstract
Operation
167
SupervisionCustomerServiceAndInformationExpenses
(907) Supervision
168
CustomerAssistanceExpenses
(908) Customer Assistance Expenses
56,792,244
37,985,667
169
InformationalAndInstructionalAdvertisingExpenses
(909) Informational and Instructional Expenses
10,904,114
12,655,336
170
MiscellaneousCustomerServiceAndInformationalExpenses
(910) Miscellaneous Customer Service and Informational Expenses
171
CustomerServiceAndInformationExpenses
TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)
67,696,358
50,641,003
172
SalesExpenseAbstract
7. SALES EXPENSES
173
SalesExpenseOperationAbstract
Operation
174
SupervisionSalesExpense
(911) Supervision
175
DemonstratingAndSellingExpenses
(912) Demonstrating and Selling Expenses
176
AdvertisingExpenses
(913) Advertising Expenses
177
MiscellaneousSalesExpenses
(916) Miscellaneous Sales Expenses
178
SalesExpenses
TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)
179
AdministrativeAndGeneralExpensesAbstract
8. ADMINISTRATIVE AND GENERAL EXPENSES
180
AdministrativeAndGeneralExpensesOperationAbstract
Operation
181
AdministrativeAndGeneralSalaries
(920) Administrative and General Salaries
63,144,769
54,461,993
182
OfficeSuppliesAndExpenses
(921) Office Supplies and Expenses
26,068,215
24,072,201
183
AdministrativeExpensesTransferredCredit
(Less) (922) Administrative Expenses Transferred-Credit
72,257,203
55,017,767
184
OutsideServicesEmployed
(923) Outside Services Employed
290,621,265
247,635,892
185
PropertyInsurance
(924) Property Insurance
2,301,581
2,272,568
186
InjuriesAndDamages
(925) Injuries and Damages
32,482,933
20,785,264
187
EmployeePensionsAndBenefits
(926) Employee Pensions and Benefits
111,874,535
74,976,530
188
FranchiseRequirements
(927) Franchise Requirements
42,867,222
37,509,540
189
RegulatoryCommissionExpenses
(928) Regulatory Commission Expenses
7,763,185
9,224,259
190
DuplicateChargesCredit
(929) (Less) Duplicate Charges-Cr.
42,867,222
37,509,540
191
GeneralAdvertisingExpenses
(930.1) General Advertising Expenses
3,531,084
8,455,675
192
MiscellaneousGeneralExpenses
(930.2) Miscellaneous General Expenses
11,894,831
10,424,781
193
RentsAdministrativeAndGeneralExpense
(931) Rents
1,193,352
2,721,104
194
AdministrativeAndGeneralOperationExpense
TOTAL Operation (Enter Total of Lines 181 thru 193)
478,618,547
400,012,500
195
AdministrativeAndGeneralExpensesMaintenanceAbstract
Maintenance
196
MaintenanceOfGeneralPlant
(935) Maintenance of General Plant
43,253,140
41,192,422
197
AdministrativeAndGeneralExpenses
TOTAL Administrative & General Expenses (Total of Lines 194 and 196)
521,871,687
441,204,922
198
OperationsAndMaintenanceExpensesElectric
TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)
(b)
4,727,323,525
(d)
4,292,331,217


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: MiscellaneousTransmissionExpenses
Included in Account 566 (Miscellaneous Transmission Expense) are expenses (benefits) associated with the following:
For the Years Ended December 31,
2024 2023
PJM Interconnection, LLC (PJM) Related Activity:
PJM Transmission benefit $ —  $ — 
Other (1,860,693) (1,318,398)
Sub-total (PJM related activity) $ (1,860,693) $ (1,318,398)
Other Miscellaneous transmission expenses 30,043,206  26,915,274 
Total for Account 566 $ 28,182,513  $ 25,596,876 
Expenses associated with PJM were recorded in the following accounts:
For the Years Ended December 31,
2024 2023
Account 555 $ 751,593,712  $ 691,537,366 
Account 561.4 415,402,822  397,423,917 
Account 561.8 22,092,777  15,259,248 
Account 566 (1,860,693) (1,318,398)
Account 575.7 8,464,510  6,841,513 
Total $ 1,195,693,128  $ 1,109,743,646 
(b) Concept: OperationsAndMaintenanceExpensesElectric
Includes expenses for the year 2023 related to the following:
                  Postretirement benefit expenses, other than pension expenses (PBOP), of ($6,219,944)
                  Power procurement expenses of $326,428 in A&G accounts 920-935.
(c) Concept: MiscellaneousTransmissionExpenses
Refer to the footnote for Line No. 97, Column (b).
(d) Concept: OperationsAndMaintenanceExpensesElectric
Includes expenses for the year 2023 related to the following:
                  Postretirement benefit expenses, other than pension expenses (PBOP), of ($5,587,089)
                  Power procurement expenses of $295,182 in A&G accounts 920-935.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
PURCHASED POWER (Account 555)
  1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges.
  2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller.
  3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:

    RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers.

    LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract.

    IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years.

    SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less.

    LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit.

    IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years.

    EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges.

    OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment.

    AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment.

  4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided.
  5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.
  6. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange.
  7. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote.
  8. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13.
  9. Footnote entries as required and provide explanations following all required data.
Actual Demand (MW) POWER EXCHANGES COST/SETTLEMENT OF POWER
Line No.
NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
Name of Company or Public Authority (Footnote Affiliations)
(a)
StatisticalClassificationCode
Statistical Classification
(b)
RateScheduleTariffNumber
Ferc Rate Schedule or Tariff Number
(c)
AverageMonthlyBillingDemand
Average Monthly Billing Demand (MW)
(d)
AverageMonthlyNonCoincidentPeakDemand
Average Monthly NCP Demand
(e)
AverageMonthlyCoincidentPeakDemand
Average Monthly CP Demand
(f)
MegawattHoursPurchasedOtherThanStorage
MegaWatt Hours Purchased (Excluding for Energy Storage)
(g)
MegawattHoursPurchasedForEnergyStorage
MegaWatt Hours Purchased for Energy Storage
(h)
EnergyReceivedThroughPowerExchanges
MegaWatt Hours Received
(i)
EnergyDeliveredThroughPowerExchanges
MegaWatt Hours Delivered
(j)
DemandChargesOfPurchasedPower
Demand Charges ($)
(k)
EnergyChargesOfPurchasedPower
Energy Charges ($)
(l)
OtherChargesOfPurchasedPower
Other Charges ($)
(m)
SettlementOfPower
Total (k+l+m) of Settlement ($)
(n)
1
(a)
AEP Energy Partners, Inc.
224,550
7,279,436
7,279,436
2
Dynegy Marketing ad Trade, LLC
3,462,825
136,046,081
136,046,081
3
Constellation Energy Generation, LLC
1,722,725
76,444,798
76,444,798
4
J. ARON & COMPANY LLC
726,100
40,793,017
40,793,017
5
Macquarie Energy, LLC
454,200
17,584,045
17,584,045
6
Midwest Generation, LLC
107,200
3,002,372
3,002,372
7
Morgan Stanley Capital Group Inc.
1,139,525
45,975,302
45,975,302
8
Mercuria Energy America, LLC
1,210,150
44,970,901
44,970,901
9
NextEra Energy Marketing, LLC
549,675
27,919,029
27,919,029
10
NRG Power Marketing, LLC
576,575
31,037,923
31,037,923
11
Shell Energy North America (US), L.P.
784,400
36,568,060
36,568,060
12
Tidal
473,800
24,509,656
24,509,656
13
TransAlta Energy Marketing (U.S.) Inc.
386,750
21,021,620
21,021,620
14
ConocoPhillips Company
55,225
1,763,898
1,763,898
15
DRW Energy Trading LLC
8,000
279,120
279,120
16
Cogeneration
409,295
42,124,775
42,124,775
17
PJM Interconnection, LLC
20,137,848
751,593,712
751,593,712
18
Deferred Energy Costs
(b)
483,462
483,462
19
Other Net Metering Arrangements
241,866
4,240,057
4,240,057
20
Other Miscellaneous Adjustments
(c)
68,627,040
68,627,040
15 TOTAL
(d)
32,670,709
0
0
0
1,308,913,745
72,383,635
1,381,297,380


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower
This footnote pertains to Column (a) of Pages 326. Refer to Notes to Financial Statements, Page 122-123, for information regarding the Respondent's energy procurement for retail customers pursuant to the ICC-approved procurement process.
(b) Concept: OtherChargesOfPurchasedPower
The Respondent's electricity costs are recoverable or refundable under the Respondent's ICC approved rates. The Respondent recovers or refunds the difference between the actual cost of electricity and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates.
(c) Concept: OtherChargesOfPurchasedPower
Represents the settlement activity associated with the 20-year floating-to-fixed energy swap contracts entered into on December 17, 2010 with unaffiliated suppliers for the procurement of long-term renewable energy and associated RECs.
(d) Concept: MegawattHoursPurchasedOtherThanStorage
Reflects utility zone load, which includes the following amounts purchased by ComEd to serve its Full Service customers.
1Q 2024 Month MWhs
January 3,003,195 
February 2,483,577 
March 2,346,099 
Quarter Total 7,832,871 
2Q 2024 Month MWhs
April 1,965,250 
May 2,281,136 
June 3,353,019 
Quarter Total 7,599,405 
3Q 2024 Month MWhs
July 3,436,174 
August 3,380,589 
September 2,969,571 
Quarter Total 9,786,334 
4Q 2024 Month MWhs
October 2,346,387 
November 2,291,127 
December 2,814,585 
Quarter Total 7,452,099 
YTD Total 32,670,709 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
  1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c).
  3. Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c).
  4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
  5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided.
  6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract.
  7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain.
  8. Report in column (i) and (j) the total megawatthours received and delivered.
  9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
  10. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively.
  11. Footnote entries and provide explanations following all required data.
TRANSFER OF ENERGY REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Line No.
PaymentByCompanyOrPublicAuthority
Payment By (Company of Public Authority) (Footnote Affiliation)
(a)
TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName
Energy Received From (Company of Public Authority) (Footnote Affiliation)
(b)
TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName
Energy Delivered To (Company of Public Authority) (Footnote Affiliation)
(c)
StatisticalClassificationCode
Statistical Classification
(d)
RateScheduleTariffNumber
Ferc Rate Schedule of Tariff Number
(e)
TransmissionPointOfReceipt
Point of Receipt (Substation or Other Designation)
(f)
TransmissionPointOfDelivery
Point of Delivery (Substation or Other Designation)
(g)
BillingDemand
Billing Demand (MW)
(h)
TransmissionOfElectricityForOthersEnergyReceived
Megawatt Hours Received
(i)
TransmissionOfElectricityForOthersEnergyDelivered
Megawatt Hours Delivered
(j)
Demand Charges ($)
(k)
Energy Charges ($)
(l)
Other Charges ($)
(m)
RevenuesFromTransmissionOfElectricityForOthers
Total Revenues ($) (k+l+m)
(n)
1
PJM Interconnection L.L.C.
(a)
479,754,898
479,754,898
2
PJM Interconnection L.L.C.
(b)
402,821,146
402,821,146
3
PJM Interconnection L.L.C.
(c)
27,131,242
27,131,242
35 TOTAL
0
0
0
909,707,286
909,707,286


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
Network Integration Transmission Service (NITS) for Third Party Suppliers (difference between NITS Credits and Provider of Last Resort Network Integration Charges).
(b) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
Network Integration Transmission Service (NITS) for Self.
(c) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers
The details of the Other Transmission Services are as follows:
Transmission Owner Scheduling, System Control and Dispatch Service $ 22,533,473 
Other Supporting Facilities 4,597,769 
$ 27,131,242 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
TRANSMISSION OF ELECTRICITY BY ISO/RTOs
  1. Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO.
  2. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a).
  3. In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
  4. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided.
  5. In column (d) report the revenue amounts as shown on bills or vouchers.
  6. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.
Payment Received by (Transmission Owner Name)
(a)
Statistical Classification
(b)
FERC Rate Schedule or Tariff Number
(c)
Total Revenue by Rate Schedule or Tariff
(d)
Total Revenue
(e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40
TOTAL


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
  1. Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter.
  2. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported.
  3. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:
    FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications.
  4. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service.
  5. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
  6. Enter ""TOTAL"" in column (a) as the last line.
  7. Footnote entries and provide explanations following all required data.
TRANSFER OF ENERGY EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.
NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers
Name of Company or Public Authority (Footnote Affiliations)
(a)
StatisticalClassificationCode
Statistical Classification
(b)
TransmissionOfElectricityByOthersEnergyReceived
MegaWatt Hours Received
(c)
TransmissionOfElectricityByOthersEnergyDelivered
MegaWatt Hours Delivered
(d)
DemandChargesTransmissionOfElectricityByOthers
Demand Charges ($)
(e)
EnergyChargesTransmissionOfElectricityByOthers
Energy Charges ($)
(f)
OtherChargesTransmissionOfElectricityByOthers
Other Charges ($)
(g)
ChargesForTransmissionOfElectricityByOthers
Total Cost of Transmission ($)
(h)
1
Commonwealth Edison Company of Indiana, Inc.
(a)
10,271,201
10,271,201
TOTAL
0
0
0
0
10,271,201
10,271,201


FOOTNOTE DATA

(a) Concept: OtherChargesTransmissionOfElectricityByOthers
Commonwealth Edison Company of Indiana, Inc., a 100% owned subsidiary of the Respondent, provides transmission service to the Respondent under a service agreement.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.
Description
(a)
Amount
(b)
1
IndustryAssociationDues
Industry Association Dues
842,152
2
NuclearPowerResearchExpenses
Nuclear Power Research Expenses
3
OtherExperimentalAndGeneralResearchExpenses
Other Experimental and General Research Expenses
4
PublicationAndDistributionExpensesForSecuritiesToStockholders
Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities
5
OtherMiscellaneousGeneralExpenses
Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6
Accrued Vacation Pay
3,733,621
7
Environmental remediation expenses
1,163,834
8
Other environmental expenses
36,787
9
Director's fees and expenses
336,177
10
Sale or write-off of materials and supplies
373,660
11
Bank Fees
1,096,750
12
Undistributed employee expenses
198,518
13
Information technology upgrades expenses
894,404
14
Residential Time of Use Pricing Pilot Development and Operation
386,830
15
Smart meter network professional services and other costs
282,759
16
Miscellaneous Adjustments
2,549,339
46
MiscellaneousGeneralExpenses
TOTAL
11,894,831


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
  1. Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405).
  2. Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year.
  3. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year.
    Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used.
    In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used.
    For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis.
  4. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
A. Summary of Depreciation and Amortization Charges
Line No.
FunctionalClassificationAxis
Functional Classification
(a)
DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments
Depreciation Expense (Account 403)
(b)
DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments
Depreciation Expense for Asset Retirement Costs (Account 403.1)
(c)
AmortizationOfLimitedTermPlantOrProperty
Amortization of Limited Term Electric Plant (Account 404)
(d)
AmortizationOfOtherElectricPlant
Amortization of Other Electric Plant (Acc 405)
(e)
DepreciationAndAmortization
Total
(f)
1
Intangible Plant
(a)
130,027,166
130,027,166
2
Steam Production Plant
3
Nuclear Production Plant
4
Hydraulic Production Plant-Conventional
5
Hydraulic Production Plant-Pumped Storage
6
Other Production Plant
7
Transmission Plant
171,649,041
203,858
94,329
171,947,228
8
Distribution Plant
754,188,674
1,321,985
197,459
755,708,118
9
Regional Transmission and Market Operation
10
General Plant
126,439,677
304,317
883,668
(b)
125,860,326
11
Common Plant-Electric
12
TOTAL
1,052,277,392
1,830,160
129,435,286
1,183,542,838
B. Basis for Amortization Charges
See footnote data for Page 336, Line No. 1, Column (d) for required information.
C. Factors Used in Estimating Depreciation Charges
Line No.
AccountNumberFactorsUsedInEstimatingDepreciationCharges
Account No.
(a)
DepreciablePlantBase
Depreciable Plant Base (in Thousands)
(b)
UtilityPlantEstimatedAverageServiceLife
Estimated Avg. Service Life
(c)
UtilityPlantNetSalvageValuePercentage
Net Salvage (Percent)
(d)
UtilityPlantAppliedDepreciationRate
Applied Depr. Rates (Percent)
(e)
MortalityCurveType
Mortality Curve Type
(f)
UtilityPlantWeightedAverageRemainingLife
Average Remaining Life
(g)
12
6,784,364
63 years
44
(e)
2.53
47 years, 8 months, 50 days
13
14
19,709,820
54 years
46
(f)
2.75
43 years, 3 months, 10 days
15
4,336,267
59 years
38
(g)
2.5
44 years, 5 months, 14 days
16
1,687,787
35 years
2.33
SQ
22 years, 3 months, 19 days
17
48
0 years
0 years
18
806,671
15 years
15
7.87
SQ
9 years, 6 months
19
58,657
35 years
10
3.29
SQ
24 years, 3 months, 19 days
20
21
811,234
50 years
20
2.6
R1
41 years, 6 months
22
123,424
5 years
19.99
SQ
2 years, 10 months, 25 days
23
41,968
15 years
6.67
SQ
9 years, 10 months, 25 days
24
305
10 years
10
SQ
5 years
25
26
5,759
8 years
10
10.92
R3
3 years, 10 months, 25 days
27
1,087
15 years
10
1.24
R2.5
3 years, 2 months, 13 days
28
25,127
18 years
15
4.41
S0
13 years, 6 months
29
93,599
10 years
10
7.45
R1.5
6 years
30
378,004
14 years
10
5.86
S1.5
9 years, 2 months, 13 days
31
8,264
15 years
6.67
SQ
10 years, 1 month, 5 days
32
274,307
25 years
4
SQ
14 years, 8 months, 13 days
33
19,049
15 years
6.67
SQ
11 years, 7 months, 5 days
34
7,741
15 years
5
6.63
L3
6 years, 7 months, 5 days
35
274,047
15 years
10
7.33
SQ
9 years, 4 months, 25 days
36
180,039
10 years
10
11
SQ
5 years, 1 month, 5 days
37
833,023
20 years
10
2.27
L2
14 years, 3 months, 19 days
38
44
12 years
10
9.17
SQ
6 years, 6 months
39
19,916
15 years
6.67
SQ
10 years, 8 months, 50 days
40


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: AmortizationOfLimitedTermPlantOrProperty
The amortization charges shown in Column (d), Line 1 - Intangible Plant represent the straight-line amortization of the development costs of the following software:
System Avg Remaining Life in Years
Fusion SW 0*
Common MDM 0*
BIDA Customer Proj 0*
BIDA SESII Enhance 0*
Robotic Process SW 0*
Digital Strgy Epay 0*
EU North Star RE 0*
CIS Transformation 1
EU Custon Analytic 1
ISUM 2020 SW 1
EMS Implementation 1
BIDA AMI 2
GIS 2
EU SW Electric 2
Grid FR 2
Misc Comp Software FR 2
SES 2
BIDA Grid EOL 2
Cloud Serv 3 yr 3
Mobile App 4
IVR Convergence 4
EU Dig Prgm: Web 4
Port Mgmt Tool 4
SAM SW 4
UI Plan SW 4
Cloud Serv 5 yr 5
*Fully amortized during 2024.

The amortization charges shown in Column (d), Line 1 - Intangible Plant, represent the straight line amortization of the development costs related to software. See note for Column (d) line 1 for additional details regarding the system software included in Intangible Plant. Note that software is typically amortized over a 5 year period unless another life is deemed more appropriate.

The amortization charges shown in Column (d), Line 7 and Line 8 represent the amortization of costs for three Transmission Right-of Way Easements and two Distribution Right-of Way Easement, respectively, based on the periods covered by the Easements.

The amortization charges shown in Column (d), Line 10 - General Plant represent the amortization of three leasehold improvements over the lives of the respective leases.
(b) Concept: DepreciationAndAmortization
The amount of depreciation expense associated with Account 397 (Communication Equipment) for the year 2024 is $60,626,215 - 30.18% of such amount is directly assignable to the Transmission function and 69.82% of such amount is directly assignable to the Distribution function.
(c) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
This note pertains to all plant accounts on Page 337 in Column (a), excluding transportation.

Depreciation is computed monthly by taking the monthly depreciation rate times the average depreciable plant-in-service balances at the beginning and end of each month. The amounts shown in Column (b) are the annual average depreciable plan-in-service balances computed by dividing the sum of the monthly average plant-in-service balances for the year by twelve.
(d) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges
General Notes for Page 337:

Page 337, Section C excludes all amortized Limited Term Plant (software, leasehold improvements, right of ways, etc.) as referenced in the footnote for Page 336, Line No. 1, Column (d).

The Company provides depreciation on a straight-line basis by amortizing the cost of depreciable electric plant-in-service over estimated service lives for each class of plant.

The annual average depreciable plant base for [a] Transmission, [b] Distribution - excluding HVD, Line Transformers and Meters, [c] Distribution High Voltage is reduced by $6,822,126,063, $19,796,287,020 and $4,358,623,232, respectively, related to estimated unrecorded retirements of certain plant-in-service.
(e) Concept: UtilityPlantAppliedDepreciationRate
A composite rate is calculated for all depreciation groups; therefore, an individual mortality curve is not available.
(f) Concept: UtilityPlantAppliedDepreciationRate
A composite rate is calculated for all depreciation groups; therefore, an individual mortality curve is not available.
(g) Concept: UtilityPlantAppliedDepreciationRate
A composite rate is calculated for all depreciation groups; therefore, an individual mortality curve is not available.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
REGULATORY COMMISSION EXPENSES
  1. Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party.
  2. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amounts deferred in previous years.
  3. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization.
  4. List in columns (f), (g), and (h), expenses incurred during the year which were charged currently to income, plant, or other accounts.
  5. Minor items (less than $25,000) may be grouped.
EXPENSES INCURRED DURING YEAR AMORTIZED DURING YEAR
CURRENTLY CHARGED TO
Line No.
RegulatoryCommissionDescription
Description (Furnish name of regulatory commission or body the docket or case number and a description of the case)
(a)
RegulatoryExpensesAssessedByRegulatoryCommission
Assessed by Regulatory Commission
(b)
RegulatoryExpensesOfUtility
Expenses of Utility
(c)
RegulatoryCommissionExpensesAmount
Total Expenses for Current Year (b) + (c)
(d)
OtherRegulatoryAssetsRegulatoryCommissionExpenses
Deferred in Account 182.3 at Beginning of Year
(e)
NameOfDepartmentRegulatoryCommissionExpensesCharged
Department
(f)
AccountNumberRegulatoryCommissionExpensesCharged
Account No.
(g)
RegulatoryComissionExpensesIncurredAndCharged
Amount
(h)
RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets
Deferred to Account 182.3
(i)
DeferredRegulatoryCommissionExpensesAmortizedInContraAccount
Contra Account
(j)
DeferredRegulatoryCommissionExpensesAmortized
Amount
(k)
OtherRegulatoryAssetsRegulatoryCommissionExpenses
Deferred in Account 182.3 End of Year
(l)
1
Illinois Commerce Commission
2
-------------------------------------
3
Docket Nos. -
4
20-0629, 22-0424, 22-0520, 22-0784, 23-0197, 23-0269,
5
23-0341, 23-0355, 23-0476, 23-0503, 23-0504, 23-0553,
6
23-0610, 23-0622, 23-0675, 23-0710, 23-0722, 23-0731,
7
23-0734, 23-0743, 23-0770, 23-0834, 24-0036, 24-0048,
8
24-0049, 24-0147, 24-0266, 24-0272, 24-0313, 24-0460,
9
24-0532, 24-0586, 24-0617, 24-0680, 24-0711, 24-0813,
10
24-0866, 24-0896, 24-0912, 24-0915, 24-0916,
11
Various complaint and petition matters
221,000
221,000
221,000
12
Docket No.  22-0067  Performance Metrics
124,777
124,777
124,777
13
Docket No.  22-0653  Part 280
27,635
27,635
27,635
14
Docket No. 24-0163 Low Income Rate Study
317,090
317,090
317,090
15
Docket No.  docket anticipated  Value of DER
681,129
681,129
681,129
16
Docket No.  24-0304  Annual Formula rate update and revenue reconciliation
84,922
84,922
84,922
17
Docket No. 24-0181 Refiled Grid Plan
77,022
77,022
77,022
18
Docket No.  23-0773  Rider IMUD
53,840
53,840
53,840
19
Docket No. 23-0055 Verified Petition for Approval of a Multi-Year Rate Plan - amortized over 4 years (2024-2027)
1,404,854
1,404,854
5,221,171
5,197,182
6,796,828
3,004,500
9,013,499
20
Annual Ethics & Compliance Fees
627,371
627,371
627,371
21
Various ICC dockets
42,410
42,410
42,410
22
Federal Energy Regulatory Commission
23
Deferred Tax Recovery
1,400
1,400
1,400
24
Docket No. FA21-5-000 - FERC Audit
223,168
223,168
223,168
25
Various FERC dockets
84,239
84,239
84,239
46
TOTAL
3,970,857
3,970,857
5,221,171
7,763,185
6,796,828
3,004,500
9,013,499


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
  1. Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identify recipient regardless of affiliation.) For any R, D and D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts).
  2. Indicate in column (a) the applicable classification, as shown below:
    Classifications:
    1. Electric R, D and D Performed Internally:
      1. Generation
        1. hydroelectric
          1. Recreation fish and wildlife
          2. Other hydroelectric
        2. Fossil-fuel steam
        3. Internal combustion or gas turbine
        4. Nuclear
        5. Unconventional generation
        6. Siting and heat rejection
      2. Transmission
        1. Overhead
        2. Underground
      3. Distribution
      4. Regional Transmission and Market Operation
      5. Environment (other than equipment)
      6. Other (Classify and include items in excess of $50,000.)
      7. Total Cost Incurred
    2. Electric, R, D and D Performed Externally:
      1. Research Support to the electrical Research Council or the Electric Power Research Institute
      2. Research Support to Edison Electric Institute
      3. Research Support to Nuclear Power Groups
      4. Research Support to Others (Classify)
      5. Total Cost Incurred
  3. Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D and D activity.
  4. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e).
  5. Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year.
  6. If costs have not been segregated for R, D and D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by ""Est.""
  7. Report separately research and related testing facilities operated by the respondent.
AMOUNTS CHARGED IN CURRENT YEAR
Line No.
ResearchDevelopmentAndDemonstrationClassification
Classification
(a)
ResearchDevelopmentAndDemonstrationDescription
Description
(b)
ResearchDevelopmentAndDemonstrationCostsIncurredInternally
Costs Incurred Internally Current Year
(c)
ResearchDevelopmentAndDemonstrationCostsIncurredExternally
Costs Incurred Externally Current Year
(d)
AccountNumberForResearchDevelopmentAndDemonstrationCosts
Amounts Charged In Current Year: Account
(e)
ResearchDevelopmentAndDemonstrationCosts
Amounts Charged In Current Year: Amount
(f)
ResearchDevelopmentAndDemonstrationExpenditures
Unamortized Accumulation
(g)
1
B-1
EPRI Selected Programs
397,746
397,746
2
B-1
EPRI Selected Programs
738,672
738,672
3
B-2
CEA Technologies Inc. Program
88,126
88,126
4
B-2
CEA Technologies Inc. Program
30,963
30,963
5
B-2
Georgia Tech Research Corp. - NEETRAC
25,525
25,525
6
B-2
Georgia Tech Research Corp. - NEETRAC
26,567
26,567
7
B-2
Watson & Renner
17,014
17,014
8
B-2
Watson & Renner
17,014
17,014
9
Total
1,341,627
1,341,627


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
DISTRIBUTION OF SALARIES AND WAGES

Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used.

Line No.
Classification
(a)
Direct Payroll Distribution
(b)
Allocation of Payroll Charged for Clearing Accounts
(c)
Total
(d)
1
SalariesAndWagesElectricAbstract
Electric
2
SalariesAndWagesElectricOperationAbstract
Operation
3
SalariesAndWagesElectricOperationProduction
Production
1,131,060
4
SalariesAndWagesElectricOperationTransmission
Transmission
28,305,834
5
SalariesAndWagesElectricOperationRegionalMarket
Regional Market
6
SalariesAndWagesElectricOperationDistribution
Distribution
66,531,271
7
SalariesAndWagesElectricOperationCustomerAccounts
Customer Accounts
108,004,844
8
SalariesAndWagesElectricOperationCustomerServiceAndInformational
Customer Service and Informational
6,850,875
9
SalariesAndWagesElectricOperationSales
Sales
10
SalariesAndWagesElectricOperationAdministrativeAndGeneral
Administrative and General
62,149,600
11
SalariesAndWagesElectricOperation
TOTAL Operation (Enter Total of lines 3 thru 10)
272,973,484
12
SalariesAndWagesElectricMaintenanceAbstract
Maintenance
13
SalariesAndWagesElectricMaintenanceProduction
Production
14
SalariesAndWagesElectricMaintenanceTransmission
Transmission
19,091,636
15
SalariesAndWagesElectricMaintenanceRegionalMarket
Regional Market
16
SalariesAndWagesElectricMaintenanceDistribution
Distribution
95,369,791
17
SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral
Administrative and General
3,855,915
18
SalariesAndWagesElectricMaintenance
TOTAL Maintenance (Total of lines 13 thru 17)
118,317,342
19
SalariesAndWagesElectricOperationAndMaintenanceAbstract
Total Operation and Maintenance
20
SalariesAndWagesElectricProduction
Production (Enter Total of lines 3 and 13)
1,131,060
21
SalariesAndWagesElectricTransmission
Transmission (Enter Total of lines 4 and 14)
47,397,470
22
SalariesAndWagesElectricRegionalMarket
Regional Market (Enter Total of Lines 5 and 15)
23
SalariesAndWagesElectricDistribution
Distribution (Enter Total of lines 6 and 16)
161,901,062
24
SalariesAndWagesElectricCustomerAccounts
Customer Accounts (Transcribe from line 7)
108,004,844
25
SalariesAndWagesElectricCustomerServiceAndInformational
Customer Service and Informational (Transcribe from line 8)
6,850,875
26
SalariesAndWagesElectricSales
Sales (Transcribe from line 9)
27
SalariesAndWagesElectricAdministrativeAndGeneral
Administrative and General (Enter Total of lines 10 and 17)
66,005,515
28
SalariesAndWagesElectricOperationAndMaintenance
TOTAL Oper. and Maint. (Total of lines 20 thru 27)
391,290,826
109,137,339
500,428,165
29
SalariesAndWagesGasAbstract
Gas
30
SalariesAndWagesGasOperationAbstract
Operation
31
SalariesAndWagesGasOperationProductionManufacturedGas
Production - Manufactured Gas
32
SalariesAndWagesGasOperationProductionNaturalGas
Production-Nat. Gas (Including Expl. And Dev.)
33
SalariesAndWagesGasOperationOtherGasSupply
Other Gas Supply
34
SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing
Storage, LNG Terminaling and Processing
35
SalariesAndWagesGasOperationTransmission
Transmission
36
SalariesAndWagesGasOperationDistribution
Distribution
37
SalariesAndWagesGasCustomerAccounts
Customer Accounts
38
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational
39
SalariesAndWagesGasSales
Sales
40
SalariesAndWagesGasOperationAdministrativeAndGeneral
Administrative and General
41
SalariesAndWagesGasOperation
TOTAL Operation (Enter Total of lines 31 thru 40)
42
SalariesAndWagesGasMaintenanceAbstract
Maintenance
43
SalariesAndWagesGasMaintenanceProductionManufacturedGas
Production - Manufactured Gas
44
SalariesAndWagesGasMaintenanceProductionNaturalGas
Production-Natural Gas (Including Exploration and Development)
45
SalariesAndWagesGasMaintenanceOtherGasSupply
Other Gas Supply
46
SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing
Storage, LNG Terminaling and Processing
47
SalariesAndWagesGasMaintenanceTransmission
Transmission
48
SalariesAndWagesGasMaintenanceDistribution
Distribution
49
SalariesAndWagesGasMaintenanceAdministrativeAndGeneral
Administrative and General
50
SalariesAndWagesGasMaintenance
TOTAL Maint. (Enter Total of lines 43 thru 49)
51
SalariesAndWagesGasOperationAndMaintenanceAbstract
Total Operation and Maintenance
52
SalariesAndWagesGasProductionManufacturedGas
Production-Manufactured Gas (Enter Total of lines 31 and 43)
53
SalariesAndWagesGasProductionNaturalGas
Production-Natural Gas (Including Expl. and Dev.) (Total lines 32,
54
SalariesAndWagesGasOtherGasSupply
Other Gas Supply (Enter Total of lines 33 and 45)
55
SalariesAndWagesGasStorageLngTerminalingAndProcessing
Storage, LNG Terminaling and Processing (Total of lines 31 thru
56
SalariesAndWagesGasTransmission
Transmission (Lines 35 and 47)
57
SalariesAndWagesGasDistribution
Distribution (Lines 36 and 48)
58
SalariesAndWagesGasCustomerAccounts
Customer Accounts (Line 37)
59
SalariesAndWagesGasCustomerServiceAndInformational
Customer Service and Informational (Line 38)
60
SalariesAndWagesGasSales
Sales (Line 39)
61
SalariesAndWagesGasAdministrativeAndGeneral
Administrative and General (Lines 40 and 49)
62
SalariesAndWagesGasOperationAndMaintenance
TOTAL Operation and Maint. (Total of lines 52 thru 61)
63
SalariesAndWagesOtherUtilityDepartmentsAbstract
Other Utility Departments
64
SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance
Operation and Maintenance
65
SalariesAndWagesOperationsAndMaintenance
TOTAL All Utility Dept. (Total of lines 28, 62, and 64)
391,290,826
109,137,339
500,428,165
66
SalariesAndWagesUtilityPlantAbstract
Utility Plant
67
SalariesAndWagesUtilityPlantConstructionAbstract
Construction (By Utility Departments)
68
SalariesAndWagesUtilityPlantConstructionElectricPlant
Electric Plant
416,663,068
151,175,878
567,838,946
69
SalariesAndWagesUtilityPlantConstructionGasPlant
Gas Plant
70
SalariesAndWagesUtilityPlantConstructionOther
Other (provide details in footnote):
71
SalariesAndWagesUtilityPlantConstruction
TOTAL Construction (Total of lines 68 thru 70)
416,663,068
151,175,878
567,838,946
72
SalariesAndWagesPlantRemovalAbstract
Plant Removal (By Utility Departments)
73
SalariesAndWagesPlantRemovalElectricPlant
Electric Plant
44,787,083
12,014,965
56,802,048
74
SalariesAndWagesPlantRemovalGasPlant
Gas Plant
75
SalariesAndWagesPlantRemovalOther
Other (provide details in footnote):
76
SalariesAndWagesPlantRemoval
TOTAL Plant Removal (Total of lines 73 thru 75)
44,787,083
12,014,965
56,802,048
77
SalariesAndWagesOtherAccountsAbstract
Other Accounts (Specify, provide details in footnote):
78
SalariesAndWagesOtherAccountsDescription
Other Accounts (Specify, provide details in footnote):
79
SalariesAndWagesOtherAccountsDescription
Stores Expense Undistributed
20,613,226
20,613,226
80
SalariesAndWagesOtherAccountsDescription
Clearing Accounts
74,447,034
74,447,034
81
SalariesAndWagesOtherAccountsDescription
Miscellaneous
(a)
37,464,376
37,464,376
82
SalariesAndWagesOtherAccountsDescription
83
SalariesAndWagesOtherAccountsDescription
84
SalariesAndWagesOtherAccountsDescription
85
SalariesAndWagesOtherAccountsDescription
86
SalariesAndWagesOtherAccountsDescription
87
SalariesAndWagesOtherAccountsDescription
88
SalariesAndWagesOtherAccountsDescription
89
SalariesAndWagesOtherAccountsDescription
90
SalariesAndWagesOtherAccountsDescription
91
SalariesAndWagesOtherAccountsDescription
92
SalariesAndWagesOtherAccountsDescription
93
SalariesAndWagesOtherAccountsDescription
94
SalariesAndWagesOtherAccountsDescription
95
SalariesAndWagesOtherAccounts
TOTAL Other Accounts
132,524,636
95,060,260
37,464,376
96
SalariesAndWagesGeneralExpense
TOTAL SALARIES AND WAGES
985,265,613
177,267,922
1,162,533,535


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: SalariesAndWagesOtherAccounts
Includes direct labor charges related to non-utility operations.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
COMMON UTILITY PLANT AND EXPENSES
  1. Describe the property carried in the utility's accounts as common utility plant and show the book cost of such plant at end of year classified by accounts as provided by Electric Plant Instruction 13, Common Utility Plant, of the Uniform System of Accounts. Also show the allocation of such plant costs to the respective departments using the common utility plant and explain the basis of allocation used, giving the allocation factors.
  2. Furnish the accumulated provisions for depreciation and amortization at end of year, showing the amounts and classifications of such accumulated provisions, and amounts allocated to utility departments using the common utility plant to which such accumulated provisions relate, including explanation of basis of allocation and factors used.
  3. Give for the year the expenses of operation, maintenance, rents, depreciation, and amortization for common utility plant classified by accounts as provided by the Uniform System of Accounts. Show the allocation of such expenses to the departments using the common utility plant to which such expenses are related. Explain the basis of allocation used and give the factors of allocation.
  4. Give date of approval by the Commission for use of the common utility plant classification and reference to the order of the Commission or other authorization.


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
  1. The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.
Description of Item(s)
(a)
Balance at End of Quarter 1
(b)
Balance at End of Quarter 2
(c)
Balance at End of Quarter 3
(d)
Balance at End of Year
(e)
1 Energy
2 Net Purchases (Account 555)
178,225,908
347,282,581
601,426,073
(a)
751,593,712
2.1 Net Purchases (Account 555.1)
3 Net Sales (Account 447)
3,748,882
8,576,542
16,437,338
20,927,736
4 Transmission Rights
5 Ancillary Services
10,510,664
22,777,922
33,804,810
(b)
44,595,812
6 Other Items (list separately)
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46 TOTAL
192,485,454
378,637,045
651,668,221
817,117,260


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: IsoOrRtoSettlementsEnergyNetPurchasesPurchasedPower
Amounts reported in Line Nos. 2, 3 & 5 reflect the year-to-date activities through the end of the applicable quarter.
(b) Concept: IsoOrRtoSettlementsAncillaryServices
Purchases and sales of ancillary services were recorded in the following accounts:
Purchases
Account 555 $ 43,037,882 
Account 561.4 14,870,870 
Account 561.8 756,023 
Account 575.7 8,464,510 
Sales
Account 456.1 (22,533,473)
Total $ 44,595,812 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
PURCHASES AND SALES OF ANCILLARY SERVICES
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff.
In columns for usage, report usage-related billing determinant and the unit of measure.
  1. On Line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year.
  2. On Line 2 columns (b), (c), (d), and (e) report the amount of reactive supply and voltage control services purchased and sold during the year.
  3. On Line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year.
  4. On Line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year.
  5. On Lines 5 and 6, columns (b), (c), (d), and (e) report the amount of operating reserve spinning and supplement services purchased and sold during the period.
  6. On Line 7 columns (b), (c), (d), and (e) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided.
Amount Purchased for the Year Amount Sold for the Year
Usage - Related Billing Determinant Usage - Related Billing Determinant
Line No.
Type of Ancillary Service
(a)
Number of Units
(b)
Unit of Measure
(c)
Dollar
(d)
Number of Units
(e)
Unit of Measure
(f)
Dollars
(g)
1
Scheduling, System Control and Dispatch
32,119,127
MWH
22,369,917
93,285,395
MWH
(a)
22,533,473
2
Reactive Supply and Voltage
(b)
21,854,247
3
Regulation and Frequency Response
(c)
7,242,818
4
Energy Imbalance
5
Operating Reserve - Spinning
(d)
3,436,049
6
Operating Reserve - Supplement
(e)
6,628,616
7
Other
(f)
5,597,638
8
Total (Lines 1 thru 7)
32,119,127
67,129,285
93,285,395
22,533,473


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: AncillaryServicesSoldAmount
Represents revenues allocated to the respondent from PJM Interconnection, LLC.
(b) Concept: AncillaryServicesPurchasedAmount
Represents the per load ratio share.
(c) Concept: AncillaryServicesPurchasedAmount
This footnote applies to the cells in lines 3, 5, and 6, column d. The number of units applicable to Line No. 3, Column (b) is 32,119,127.
(d) Concept: AncillaryServicesPurchasedAmount
This footnote applies to the cells in lines 3, 5, and 6, column d. The number of units applicable to Line No. 3, Column (b) is 32,119,127.
(e) Concept: AncillaryServicesPurchasedAmount
This footnote applies to the cells in lines 3, 5, and 6, column d. The number of units applicable to Line No. 3, Column (b) is 32,119,127.
(f) Concept: AncillaryServicesPurchasedAmount
The details of this "Other" amount are as follows:
Black Start service charge $ 3,889,994 
Schedule 10 - NERC charges 696,008 
Schedule 10 - RFC charges 1,005,279 
Reconciliation of Schedule 10 charges 956 
Consumer Advocates of PJM States, Inc. (CAPS) 19,244 
Fuel Cost Policy Penalty (13,843)
$ 5,597,638 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
MONTHLY TRANSMISSION SYSTEM PEAK LOAD
  1. Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.
Month
(a)
Monthly Peak MW - Total
(b)
Day of Monthly Peak
(c)
Hour of Monthly Peak
(d)
Firm Network Service for Self
(e)
Firm Network Service for Others
(f)
Long-Term Firm Point-to-point Reservations
(g)
Other Long-Term Firm Service
(h)
Short-Term Firm Point-to-point Reservation
(i)
Other Service
(j)
NAME OF SYSTEM: 0
1
January
15,077
16
(a)
17
6,029
9,048
2
February
11,845
16
18
4,243
7,602
3
March
11,534
19
7
3,674
7,860
4
Total for Quarter 1
13,946
24,510
0
0
0
0
5
April
11,472
3
9
3,625
7,847
6
May
16,015
21
17
6,567
9,448
7
June
19,874
17
17
9,161
10,713
8
Total for Quarter 2
19,353
28,008
0
0
0
0
9
July
19,220
15
17
8,716
10,504
10
August
21,560
27
16
9,821
11,739
11
September
16,871
20
16
7,110
9,761
12
Total for Quarter 3
25,647
32,004
0
0
0
0
13
October
11,806
30
15
3,616
8,190
14
November
12,040
21
17
4,311
7,729
15
December
14,063
12
17
5,447
8,616
16
Total for Quarter 4
13,374
24,535
0
0
0
0
17
Total
72,320
109,057
0
0
0
0


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: HourOfMonthlyPeakExcludingIsoAndRto
All hours reported in Column (d) are presented in Central Standard Time (CST) since ComEd Operations are in that time zone.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
Monthly ISO/RTO Transmission System Peak Load
  1. Report the monthly peak load on the respondent's transmission system. If the Respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system.
  2. Report on Column (b) by month the transmission system's peak load.
  3. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).
  4. Report on Columns (e) through (i) by month the system’s transmission usage by classification. Amounts reported as Through and Out Service in Column (g) are to be excluded from those amounts reported in Columns (e) and (f).
  5. Amounts reported in Column (j) for Total Usage is the sum of Columns (h) and (i).
Line No.
Month
(a)
Monthly Peak MW - Total
(b)
Day of Monthly Peak
(c)
Hour of Monthly Peak
(d)
Import into ISO/RTO
(e)
Exports from ISO/RTO
(f)
Through and Out Service
(g)
Network Service Usage
(h)
Point-to-Point Service Usage
(i)
Total Usage
(j)
NAME OF SYSTEM: 0
1
January
2
February
3
March
4
Total for Quarter 1
0
0
0
0
0
0
5
April
6
May
7
June
8
Total for Quarter 2
0
0
0
0
0
0
9
July
10
August
11
September
12
Total for Quarter 3
0
0
0
0
0
0
13
October
14
November
15
December
16
Total for Quarter 4
0
0
0
0
0
0
17
Total Year to Date/Year
0
0
0
0
0
0


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2024-12-31
Year/Period of Report

End of:
2024
/
Q4
ELECTRIC ENERGY ACCOUNT

Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.

Line No. Item
(a)
MegaWatt Hours
(b)
Line No. Item
(a)
MegaWatt Hours
(b)
1
SOURCES OF ENERGY
21
DISPOSITION OF ENERGY
2
Generation (Excluding Station Use):
22
Sales to Ultimate Consumers (Including Interdepartmental Sales)
(a)(b)
84,331,195
3
Steam
23
Requirements Sales for Resale (See instruction 4, page 311.)
4
Nuclear
24
Non-Requirements Sales for Resale (See instruction 4, page 311.)
791,465
5
Hydro-Conventional
25
Energy Furnished Without Charge
394,273
6
Hydro-Pumped Storage
26
Energy Used by the Company (Electric Dept Only, Excluding Station Use)
7
Other
27
Total Energy Losses
5,897,079
8
Less Energy for Pumping
27.1
Total Energy Stored
9
Net Generation (Enter Total of lines 3 through 8)
0
28
TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES
91,414,012
10
Purchases (other than for Energy Storage)
(c)
32,670,709
10.1
Purchases for Energy Storage
0
11
Power Exchanges:
12
Received
0
13
Delivered
0
14
Net Exchanges (Line 12 minus line 13)
0
15
Transmission For Other (Wheeling)
16
Received
58,743,303
17
Delivered
18
Net Transmission for Other (Line 16 minus line 17)
58,743,303
19
Transmission By Others Losses
20
TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19)
91,414,012


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

2024-12-31
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: MegawattHoursSoldSalesToUltimateConsumers
MWh's for the Years Ended December 31,
2024 2023
Retail deliveries for Full Service
$ 30,116,920  $ 29,964,172 
Retail deliveries for Delivery Only
54,214,275 52,326,049
Total retail deliveries
$ 84,331,195  $ 82,290,221 
General Notes:
Full Service reflects deliveries to customers taking electric service under tariff rates. Delivery Only service reflects customers electing to receive electricity from Alternative Retail Electric Suppliers.
(b) Concept: MegawattHoursSoldSalesToUltimateConsumers
Retail deliveries for Full Service $ 30,116,920 
Retail deliveries for Delivery Only 54,214,275 
Total Sales to Ultimate Customers $ 84,331,195 
Refer to the footnote on Page 300, line No. 10, Column (d) for additional details.
(c) Concept: MegawattHoursPurchasedOtherThanStorage
Reflects utility zone load, which includes the following amounts purchased by ComEd to serve its Full Service customers.
1Q 2024 Month MWhs
January 3,003,195 
February 2,483,577 
March 2,346,099 
Quarter Total 7,832,871 
2Q 2024 Month MWhs
April 1,965,250 
May 2,281,136 
June 3,353,019 
Quarter Total 7,599,405 
3Q 2024 Month MWhs
July 3,436,174 
August 3,380,589 
September 2,969,571 
Quarter Total 9,786,334 
4Q 2024 Month MWhs
October 2,346,387 
November 2,291,127 
December 2,814,585 
Quarter Total 7,452,099 
YTD Total 32,670,709 

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
MONTHLY PEAKS AND OUTPUT
  1. Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system.
  2. Report in column (b) by month the system’s output in Megawatt hours for each month.
  3. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales.
  4. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system.
  5. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No.
MonthAxis
Month
(a)
EnergyActivity
Total Monthly Energy
(b)
NonRequiredSalesForResaleEnergy
Monthly Non-Requirement Sales for Resale & Associated Losses
(c)
MonthlyPeakLoad
Monthly Peak - Megawatts
(d)
DayOfMonthlyPeak
Monthly Peak - Day of Month
(e)
HourOfMonthlyPeak
Monthly Peak - Hour
(f)
NAME OF SYSTEM: 0
29
January
8,176,148
31,562
15,077
16
(a)
17
30
February
6,851,534
77,657
11,845
16
18
31
March
6,942,682
48,189
11,534
19
7
32
April
6,506,082
38,372
11,472
3
9
33
May
7,038,256
42,880
16,015
21
17
34
June
8,578,764
99,261
19,874
17
17
35
July
9,019,264
129,310
19,220
15
17
36
August
9,084,276
60,962
21,560
27
16
37
September
7,680,383
70,885
16,871
20
16
38
October
6,852,062
78,261
11,806
30
15
39
November
6,806,358
62,126
12,040
21
17
40
December
7,878,203
52,000
14,063
12
17
41
Total
91,414,012
791,465


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: HourOfMonthlyPeak
Hours reported in Column (f) are presented in the Central Standard Time (CST) since ComEd operations are in that time zone.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
Steam Electric Generating Plant Statistics

1. Report data for plant in Service only.
2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants.
3. Indicate by a footnote any plant leased or operated as a joint facility.
4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.
5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.
6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mcf.
7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20.
8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
9. Items under Cost of Plant are based on USofA accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.
10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.
11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.
12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant.

Line No.
Item
(a)
Plant Name:
0
1
PlantKind
Kind of Plant (Internal Comb, Gas Turb, Nuclear)
2
PlantConstructionType
Type of Constr (Conventional, Outdoor, Boiler, etc)
3
YearPlantOriginallyConstructed
Year Originally Constructed
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
5
InstalledCapacityOfPlant
Total Installed Cap (Max Gen Name Plate Ratings-MW)
6
NetPeakDemandOnPlant
Net Peak Demand on Plant - MW (60 minutes)
7
PlantHoursConnectedToLoad
Plant Hours Connected to Load
8
NetContinuousPlantCapability
Net Continuous Plant Capability (Megawatts)
9
NetContinuousPlantCapabilityNotLimitedByCondenserWater
When Not Limited by Condenser Water
10
NetContinuousPlantCapabilityLimitedByCondenserWater
When Limited by Condenser Water
11
PlantAverageNumberOfEmployees
Average Number of Employees
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - kWh
13
CostOfLandAndLandRightsSteamProduction
Cost of Plant: Land and Land Rights
14
CostOfStructuresAndImprovementsSteamProduction
Structures and Improvements
15
CostOfEquipmentSteamProduction
Equipment Costs
16
AssetRetirementCostsSteamProduction
Asset Retirement Costs
17
CostOfPlant
Total cost (total 13 thru 20)
18
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 17/5) Including
19
OperationSupervisionAndEngineeringExpense
Production Expenses: Oper, Supv, & Engr
20
FuelSteamPowerGeneration
Fuel
21
CoolantsAndWater
Coolants and Water (Nuclear Plants Only)
22
SteamExpensesSteamPowerGeneration
Steam Expenses
23
SteamFromOtherSources
Steam From Other Sources
24
SteamTransferredCredit
Steam Transferred (Cr)
25
ElectricExpensesSteamPowerGeneration
Electric Expenses
26
MiscellaneousSteamPowerExpenses
Misc Steam (or Nuclear) Power Expenses
27
RentsSteamPowerGeneration
Rents
28
Allowances
Allowances
29
MaintenanceSupervisionAndEngineeringSteamPowerGeneration
Maintenance Supervision and Engineering
30
MaintenanceOfStructuresSteamPowerGeneration
Maintenance of Structures
31
MaintenanceOfBoilerPlantSteamPowerGeneration
Maintenance of Boiler (or reactor) Plant
32
MaintenanceOfElectricPlantSteamPowerGeneration
Maintenance of Electric Plant
33
MaintenanceOfMiscellaneousSteamPlant
Maintenance of Misc Steam (or Nuclear) Plant
34
PowerProductionExpensesSteamPower
Total Production Expenses
0
35
ExpensesPerNetKilowattHour
Expenses per Net kWh
35
FuelKindAxis
Plant Name
36
FuelKind
Fuel Kind
37
FuelUnit
Fuel Unit
38
QuantityOfFuelBurned
Quantity (Units) of Fuel Burned
39
FuelBurnedAverageHeatContent
Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)
40
AverageCostOfFuelPerUnitAsDelivered
Avg Cost of Fuel/unit, as Delvd f.o.b. during year
41
AverageCostOfFuelPerUnitBurned
Average Cost of Fuel per Unit Burned
42
AverageCostOfFuelBurnedPerMillionBritishThermalUnit
Average Cost of Fuel Burned per Million BTU
43
AverageCostOfFuelBurnedPerKilowattHourNetGeneration
Average Cost of Fuel Burned per kWh Net Gen
44
AverageBritishThermalUnitPerKilowattHourNetGeneration
Average BTU per kWh Net Generation


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
Hydroelectric Generating Plant Statistics
  1. Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number.
  3. If net peak demand for 60 minutes is not available, give that which is available specifying period.
  4. If a group of employees attends more than one generating plant, report on line 11 the approximate average number of employees assignable to each plant.
  5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
  6. Report as a separate plant any plant equipped with combinations of steam, hydro, internal combustion engine, or gas turbine equipment.
Line No.
Item
(a)
FERC Licensed Project No.
0
Plant Name:
0
1
PlantKind
Kind of Plant (Run-of-River or Storage)
2
PlantConstructionType
Plant Construction type (Conventional or Outdoor)
3
YearPlantOriginallyConstructed
Year Originally Constructed
4
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
5
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
6
NetPeakDemandOnPlant
Net Peak Demand on Plant-Megawatts (60 minutes)
7
PlantHoursConnectedToLoad
Plant Hours Connect to Load
8
NetPlantCapabilityAbstract
Net Plant Capability (in megawatts)
9
NetPlantCapabilityUnderMostFavorableOperatingConditions
(a) Under Most Favorable Oper Conditions
10
NetPlantCapabilityUnderMostAdverseOperatingConditions
(b) Under the Most Adverse Oper Conditions
11
PlantAverageNumberOfEmployees
Average Number of Employees
12
NetGenerationExcludingPlantUse
Net Generation, Exclusive of Plant Use - kWh
13
CostOfPlantAbstract
Cost of Plant
14
CostOfLandAndLandRightsHydroelectricProduction
Land and Land Rights
15
CostOfStructuresAndImprovementsHydroelectricProduction
Structures and Improvements
16
CostOfReservoirsDamsAndWaterwaysHydroelectricProduction
Reservoirs, Dams, and Waterways
17
EquipmentCostsHydroelectricProduction
Equipment Costs
18
CostOfRoadsRailroadsAndBridgesHydroelectricProduction
Roads, Railroads, and Bridges
19
AssetRetirementCostsHydroelectricProduction
Asset Retirement Costs
20
CostOfPlant
Total cost (total 13 thru 20)
21
CostPerKilowattOfInstalledCapacity
Cost per KW of Installed Capacity (line 20 / 5)
22
ProductionExpensesAbstract
Production Expenses
23
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
24
WaterForPower
Water for Power
25
HydraulicExpenses
Hydraulic Expenses
26
ElectricExpensesHydraulicPowerGeneration
Electric Expenses
27
MiscellaneousHydraulicPowerGenerationExpenses
Misc Hydraulic Power Generation Expenses
28
RentsHydraulicPowerGeneration
Rents
29
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration
Maintenance Supervision and Engineering
30
MaintenanceOfStructuresHydraulicPowerGeneration
Maintenance of Structures
31
MaintenanceOfReservoirsDamsAndWaterways
Maintenance of Reservoirs, Dams, and Waterways
32
MaintenanceOfElectricPlantHydraulicPowerGeneration
Maintenance of Electric Plant
33
MaintenanceOfMiscellaneousHydraulicPlant
Maintenance of Misc Hydraulic Plant
34
PowerProductionExpensesHydraulicPower
Total Production Expenses (total 23 thru 33)
35
ExpensesPerNetKilowattHour
Expenses per net kWh


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
Pumped Storage Generating Plant Statistics
  1. Large plants and pumped storage plants of 10,000 Kw or more of installed capacity (name plate ratings).
  2. If any plant is leased, operating under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. Give project number.
  3. If net peak demand for 60 minutes is not available, give that which is available, specifying period.
  4. If a group of employees attends more than one generating plant, report on Line 8 the approximate average number of employees assignable to each plant.
  5. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
  6. Pumping energy (Line 10) is that energy measured as input to the plant for pumping purposes.
  7. Include on Line 36 the cost of energy used in pumping into the storage reservoir. When this item cannot be accurately computed leave Lines 36, 37 and 38 blank and describe at the bottom of the schedule the company's principal sources of pumping power, the estimated amounts of energy from each station or other source that individually provides more than 10 percent of the total energy used for pumping, and production expenses per net MWH as reported herein for each source described. Group together stations and other resources which individually provide less than 10 percent of total pumping energy. If contracts are made with others to purchase power for pumping, give the supplier contract number, and date of contract.
Line No.
Item
(a)
FERC Licensed Project No.
0
Plant Name:
0
1
PlantConstructionType
Type of Plant Construction (Conventional or Outdoor)
2
YearPlantOriginallyConstructed
Year Originally Constructed
3
YearLastUnitOfPlantInstalled
Year Last Unit was Installed
4
InstalledCapacityOfPlant
Total installed cap (Gen name plate Rating in MW)
5
NetPeakDemandOnPlant
Net Peak Demaind on Plant-Megawatts (60 minutes)
0
6
PlantHoursConnectedToLoad
Plant Hours Connect to Load While Generating
0
7
NetContinuousPlantCapability
Net Plant Capability (in megawatts)
0
8
PlantAverageNumberOfEmployees
Average Number of Employees
9
NetGenerationExcludingPlantUse
Generation, Exclusive of Plant Use - kWh
0
10
EnergyUsedForPumping
Energy Used for Pumping
11
NetOutputForLoad
Net Output for Load (line 9 - line 10) - Kwh
0
12
CostOfPlantAbstract
Cost of Plant
13
CostOfLandAndLandRightsPumpedStoragePlant
Land and Land Rights
14
CostOfStructuresAndImprovementsPumpedStoragePlant
Structures and Improvements
0
15
CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Reservoirs, Dams, and Waterways
0
16
CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant
Water Wheels, Turbines, and Generators
0
17
CostOfAccessoryElectricEquipmentPumpedStoragePlant
Accessory Electric Equipment
0
18
CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant
Miscellaneous Powerplant Equipment
0
19
CostOfRoadsRailroadsAndBridgesPumpedStoragePlant
Roads, Railroads, and Bridges
0
20
AssetRetirementCostsPumpedStoragePlant
Asset Retirement Costs
0
21
CostOfPlant
Total cost (total 13 thru 20)
22
CostPerKilowattOfInstalledCapacity
Cost per KW of installed cap (line 21 / 4)
23
ProductionExpensesAbstract
Production Expenses
24
OperationSupervisionAndEngineeringExpense
Operation Supervision and Engineering
0
25
WaterForPower
Water for Power
0
26
PumpedStorageExpenses
Pumped Storage Expenses
0
27
ElectricExpensesPumpedStoragePlant
Electric Expenses
0
28
MiscellaneousPumpedStoragePowerGenerationExpenses
Misc Pumped Storage Power generation Expenses
0
29
RentsPumpedStoragePlant
Rents
0
30
MaintenanceSupervisionAndEngineeringPumpedStoragePlant
Maintenance Supervision and Engineering
0
31
MaintenanceOfStructuresPumpedStoragePlant
Maintenance of Structures
0
32
MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant
Maintenance of Reservoirs, Dams, and Waterways
0
33
MaintenanceOfElectricPlantPumpedStoragePlant
Maintenance of Electric Plant
0
34
MaintenanceOfMiscellaneousPumpedStoragePlant
Maintenance of Misc Pumped Storage Plant
0
35
PowerProductionExpenseBeforePumpingExpenses
Production Exp Before Pumping Exp (24 thru 34)
36
PumpingExpenses
Pumping Expenses
37
PowerProductionExpensesPumpedStoragePlant
Total Production Exp (total 35 and 36)
38
ExpensesPerNetKilowattHour
Expenses per kWh (line 37 / 9)
39
ExpensesPerNetKilowattHourGenerationAndPumping
Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10))
0


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
GENERATING PLANT STATISTICS (Small Plants)
  1. Small generating plants are steam plants of, less than 25,000 Kw; internal combustion and gas turbine-plants, conventional hydro plants and pumped storage plants of less than 10,000 Kw installed capacity (name plate rating).
  2. Designate any plant leased from others, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, and give a concise statement of the facts in a footnote. If licensed project, give project number in footnote.
  3. List plants appropriately under subheadings for steam, hydro, nuclear, internal combustion and gas turbine plants. For nuclear, see instruction 11, Page 402.
  4. If net peak demand for 60 minutes is not available, give the which is available, specifying period.
  5. If any plant is equipped with combinations of steam, hydro internal combustion or gas turbine equipment, report each as a separate plant. However, if the exhaust heat from the gas turbine is utilized in a steam turbine regenerative feed water cycle, or for preheated combustion air in a boiler, report as one plant.
Production Expenses
Line No.
PlantName
Name of Plant
(a)
YearPlantOriginallyConstructed
Year Orig. Const.
(b)
InstalledCapacityOfPlant
Installed Capacity Name Plate Rating (MW)
(c)
NetPeakDemandOnPlant
Net Peak Demand MW (60 min)
(d)
NetGenerationExcludingPlantUse
Net Generation Excluding Plant Use
(e)
CostOfPlant
Cost of Plant
(f)
PlantCostPerMw
Plant Cost (Incl Asset Retire. Costs) Per MW
(g)
OperatingExpensesExcludingFuel
Operation Exc'l. Fuel
(h)
FuelProductionExpenses
Fuel Production Expenses
(i)
MaintenanceProductionExpenses
Maintenance Production Expenses
(j)
FuelKind
Kind of Fuel
(k)
FuelCostPerMmbtus
Fuel Costs (in cents (per Million Btu)
(l)
GenerationType
Generation Type
(m)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
ENERGY STORAGE OPERATIONS (Large Plants)
  1. Large Plants are plants of 10,000 Kw or more.
  2. In columns (a) (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location.
  3. In column (d), report Megawatt hours (MWH) purchased, generated, or received in exchange transactions for storage.
  4. In columns (e), (f) and (g) report MWHs delivered to the grid to support production, transmission and distribution. The amount reported in column (d) should include MWHs delivered/provided to a generator’s own load requirements or used for the provision of ancillary services.
  5. In columns (h), (i), and (j) report MWHs lost during conversion, storage and discharge of energy.
  6. In column (k) report the MWHs sold.
  7. In column (l), report revenues from energy storage operations. In a footnote, disclose the revenue accounts and revenue amounts related to the income generating activity.
  8. In column (m), report the cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. In columns (n) and (o), report fuel costs for storage operations associated with self-generated power included in Account 501 and other costs associated with self-generated power.
  9. In columns (q), (r) and (s) report the total project plant costs including but not exclusive of land and land rights, structures and improvements, energy storage equipment, turbines, compressors, generators, switching and conversion equipment, lines and equipment whose primary purpose is to integrate or tie energy storage assets into the power grid, and any other costs associated with the energy storage project included in the property accounts listed.
Line No.
Name of the Energy Storage Project
(a)
Functional Classification
(b)
Location of the Project
(c)
MWHs
(d)
MWHs delivered to the grid to support Production
(e)
MWHs delivered to the grid to support Transmission
(f)
MWHs delivered to the grid to support Distribution
(g)
MWHs Lost During Conversion, Storage and Discharge of Energy Production
(h)
MWHs Lost During Conversion, Storage and Discharge of Energy Transmission
(i)
MWHs Lost During Conversion, Storage and Discharge of Energy Distribution
(j)
MWHs Sold
(k)
Revenues from Energy Storage Operations
(l)
Power Purchased for Storage Operations (555.1) (Dollars)
(m)
Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars)
(n)
Other Costs Associated with Self-Generated Power (Dollars)
(o)
Account for Project Costs
(p)
Production (Dollars)
(q)
Transmission (Dollars)
(r)
Distribution (Dollars)
(s)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35 TOTAL
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
ENERGY STORAGE OPERATIONS (Small Plants)
  1. Small Plants are plants less than 10,000 Kw.
  2. In columns (a), (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location.
  3. In column (d), report project plant cost including but not exclusive of land and land rights, structures and improvements, energy storage equipment and any other costs associated with the energy storage project.
  4. In column (e), report operation expenses excluding fuel, (f), maintenance expenses, (g) fuel costs for storage operations and (h) cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined.
  5. If any other expenses, report in column (i) and footnote the nature of the item(s).
BALANCE AT BEGINNING OF YEAR
Line No.
Name of the Energy Storage Project
(a)
Functional Classification
(b)
Location of the Project
(c)
Project Cost
(d)
Operations (Excluding Fuel used in Storage Operations)
(e)
Maintenance
(f)
Cost of fuel used in storage operations
(g)
Account No. 555.1, Power Purchased for Storage Operations
(h)
Other Expenses
(i)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36 TOTAL
0
0
0
0
0
0


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
TRANSMISSION LINE STATISTICS
  1. Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. If required by a State commission to report individual lines for all voltages, do so but do not group totals for each voltage under 132 kilovolts.
  2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page.
  3. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property.
  4. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line.
  5. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated.
  6. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g).
  7. Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company.
  8. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company.
  9. Base the plant cost figures called for in columns (j) to (l) on the book cost at end of year.
DESIGNATION VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase) LENGTH (Pole miles) - (In the case of underground lines report circuit miles) COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way) EXPENSES, EXCEPT DEPRECIATION AND TAXES
Line No.
TransmissionLineStartPoint
From
TransmissionLineEndPoint
To
OperatingVoltageOfTransmissionLine
Operating
DesignedVoltageOfTransmissionLine
Designated
SupportingStructureOfTransmissionLineType
Type of Supporting Structure
LengthForStandAloneTransmissionLines
On Structure of Line Designated
LengthForTransmissionLinesAggregatedWithOtherStructures
On Structures of Another Line
NumberOfTransmissionCircuits
Number of Circuits
SizeOfConductorAndMaterial
Size of Conductor and Material
CostOfLandAndLandRightsTransmissionLines
Land
ConstructionAndOtherCostsTransmissionLines
Construction Costs
OverallCostOfTransmissionLine
Total Costs
OperatingExpensesOfTransmissionLine
Operation Expenses
MaintenanceExpensesOfTransmissionLine
Maintenance Expenses
RentExpensesOfTransmissionLine
Rents
OverallExpensesOfTransmissionLine
Total Expenses
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
1
(a)
138 KV Line
30,412,187
1,336,179,344
1,366,591,531
2
345 KV Line
91,507,142
1,427,246,217
1,518,753,359
3
765 KV Line
9,668,733
49,839,122
59,507,855
4
Overhead Line Expenses
5
Underground Line Expenses
6
765KV LINES OVERHEAD
7
2315 COLLINS
PLANO
765
765
34.41
1
4-1585 AE ACAR
8
11215 WILTON CENTER
ILL-IND STATE LINE
765
765
27.82
1
4-1277 ACAR
9
11216 WILTON CENTER - 1
COLLINS
765
765
27.09
1
4-1585 AE ACAR
10
11216 WILTON CENTER - 2
COLLINS
765
765
0.27
4-1585 AE ACAR
11
345KV LINES OVERHEAD
345kV LINES
12
0101 LASALLE - 1
PLANO
345
345
28.64
1
2-1277 ACAR
13
0101 LASALLE - 2
PLANO
345
345
12.32
2-1277 ACAR
14
0102 LASALLE - 1
PLANO
345
345
0.47
28.14
1
2-1277 ACAR
15
0102 LASALLE - 2
PLANO
345
345
12.32
2-1277 ACAR, 2-T2-1192 AAC
16
0103 LASALLE - 1
BRAIDWOOD
345
345
24.86
1
2-1277 ACAR
17
0103 LASALLE - 2
BRAIDWOOD
345
345
0.69
2-1277 ACAR
18
0104 LASALLE - 1
BRAIDWOOD
345
345
0.58
1
2-1277 ACAR
19
0104 LASALLE - 2
BRAIDWOOD
345
345
24.86
2-1277 ACAR
20
0301 POWERTON - 1
KATYDID
345
345
1.89
1
2-1277 ACAR
21
0301 POWERTON - 2
KATYDID
345
345
72.02
2-1277 ACAR
22
0302 POWERTON - 1
MOLE CREEK
345
345
1.37
1
2-1277 ACAR
23
0302 POWERTON - 2
MOLE CREEK
345
345
44.81
2-1277 ACAR
24
0303 POWERTON - 1
NEVADA
345
345
1.11
0.20
1
2-1277 ACAR
25
0303 POWERTON - 2
NEVADA
345
345
0.25
69.22
2-1277 ACAR
26
0304 POWERTON - 1
TAXEWELL (CILCO)
345
345
8.79
1
2-1277 ACAR
27
0304 POWERTON - 2
TAXEWELL (CILCO)
345
345
0.12
2-1277 ACAR
28
0403 QUAD CITIES - 1
CORDOVA
345
345
1.96
1
2-1033.5 ACSS/TW
29
0403 QUAD CITIES - 2
CORDOVA
345
345
0.17
2-1277 ACAR
30
0404 QUAD CITIES
N.W. STEEL & WIRE
345
345
33.07
1
2-1277 ACAR
31
0621 BYRON - 1
CHERRY VALLEY
345
345
0.27
13.17
1
2156 ACSR
32
0621 BYRON - 2
CHERRY VALLEY
345
345
8.07
2156 ACSR
33
0622 BYRON - 1
CHERRY VALLEY
345
345
21.51
1
2156 ACSR, 2338 A
34
0622 BYRON - 2
CHERRY VALLEY
345
345
0.03
2156 ACSR
35
0624 BYRON - 1
WEMPLETOWN
345
345
0.41
1
2156 ACSR
36
0624 BYRON - 2
WEMPLETOWN
345
345
27.87
2156 ACSR, 2-2156
37
0626 BYRON
WAYNE
345
345
59.44
1
2-1277 ACAR
38
0627 BYRON - 1
LEE COUNTY E.C.
345
345
11.11
1
2-1277 ACAR
39
0627 BYRON - 2
LEE COUNTY E.C.
345
345
0.07
2-1277 ACAR
40
0627 BYRON - 3
LEE COUNTY E.C.
345
345
0.49
2156 ACSR
41
0627 BYRON - 4
LEE COUNTY E.C.
345
345
7.80
2156 ACSR
42
0722 STATE LINE
BURNHAM
345
345
3.83
1
2338 ACAR
43
1202 DRESDEN - 1
MULBERRY
345
345
0.37
1
2156 ACSR
44
1202 DRESDEN - 2
MULBERRY
345
345
1.12
2338 ACAR
45
1220 DRESDEN - 1
ELWOOD E.C.
345
345
11.50
1
2338 ACAR
46
1220 DRESDEN - 2
ELWOOD E.C.
345
345
0.40
T2-1113 ACSR
47
1220 DRESDEN - 3
ELWOOD E.C.
345
345
0.53
2338 ACAR
48
1220 DRESDEN - 4
ELWOOD E.C.
345
345
0.16
2156 ACSR
49
1221 DRESDEN - 1
WOLFS
345
345
1.11
1
2338 ACAR
50
1221 DRESDEN - 2
WOLFS
345
345
22.72
2156 ACSR
51
1221 DRESDEN - 3
WOLFS
345
345
0.94
2156 ACSR
52
1222 DRESDEN - 1
ELWOOD E.C.
345
345
0.54
1
T2-1113,2156 ACSR
53
1222 DRESDEN - 2
ELWOOD E.C.
345
345
11.89
2338 ACAR
54
1223 DRESDEN - 1
ELECTRIC JUNCTION
345
345
0.19
28.43
1
2156 ACSR
55
1223 DRESDEN - 2
ELECTRIC JUNCTION
345
345
0.26
1.07
2338 ACAR
56
1223 DRESDEN - 3
ELECTRIC JUNCTION
345
345
0.05
1.25
2156 ACSR
57
1227 DRESDEN - 1
MULBERRY
345
345
0.56
0.18
1
2156 ACSR, 2-1033.5 ACSS/TW
58
1227 DRESDEN - 2
MULBERRY
345
345
0.11
0.69
2156 ACSR
59
1309 CRAWFORD
FISK TERMINAL
345
345
4.65
1
T2-1113 ACSR
60
1310 CRAWFORD
FISK
345
345
0.18
4.39
1
T2-1113 ACSR
61
1311 CRAWFORD - 1
GOODINGS GROVE
345
345
9.86
1
2-1277 ACAR, 2156 ACSR, 2-1033.5 ACSS/TW
62
1311 CRAWFORD - 2
GOODINGS GROVE
345
345
10.58
2156 ACSR
63
1312 CRAWFORD - 1
GOODINGS GROVE
345
345
0.33
9.62
1
2-1277 ACAR, 2156 ACSR, 2338 ACAR
64
1312 CRAWFORD - 2
GOODINGS GROVE
345
345
0.05
10.53
2156 ACSR
65
1625 WAUKEGAN
NORTHBROOK 159
345
345
0.26
21.47
1
2156 ACSR
66
1626 WAUKEGAN
NORTHBROOK 159
345
345
21.78
1
2156 ACSR
67
2001 BRAIDWOOD - 1
E. FRANKFORT
345
345
7.88
1
2-1277 ACAR
68
2001 BRAIDWOOD - 2
E. FRANKFORT
345
345
28.08
2-1277 ACAR
69
2002 BRAIDWOOD - 1
DAVIS CREEK
345
345
2.49
1
2156 ACSR
70
2002 BRAIDWOOD - 2
DAVIS CREEK
345
345
20.50
2156 ACSR
71
2003 BRAIDWOOD - 1
E. FRANKFORT
345
345
0.42
7.43
1
2-1277 ACAR
72
2003 BRAIDWOOD - 2
E. FRANKFORT
345
345
28.08
2-1277 ACAR
73
2004 BRAIDWOOD - 1
DAVIS CREEK
345
345
0.14
2.34
1
2156 ACSR
74
2004 BRAIDWOOD - 2
DAVIS CREEK
345
345
20.50
2156 ACSR
75
2101 KINCAID
LANESVILLE (AMEREN)
345
345
19.84
1
2-1277 ACAR
76
2102 KINCAID - 1
LATHAM (AMEREN)
345
345
31.14
1
2-1277 ACAR
77
2102 KINCAID - 2
LATHAM (AMEREN)
345
345
0.06
2-1277 ACAR
78
2105 KINCAID - 1
PANA
345
345
25.94
1
2338 ACAR
79
2105 KINCAID - 2
PANA
345
345
0.30
2338 ACAR
80
2105 KINCAID - 3
PANA
345
345
0.15
2338 ACAR
81
2107 MT. PULASKI - 1
LANESVILLE (AMEREN)
345
345
0.95
1
2-1277 ACAR
82
2107 MT. PULASKI - 2
LANESVILLE (AMEREN)
345
345
7.23
2-1277 ACAR
83
2218 ZION
WAUKEGAN
345
345
5.28
1
2156 ACSR
84
2219 ZION
WAUKEGAN
345
345
0.33
4.94
1
2156 ACSR
85
2221 ZION - 1
ATC
345
345
4.89
1
2156 ACSR
86
2221 ZION - 2
ATC
345
345
2.96
2156 ACSR
87
2222 ZION - 1
ATC
345
345
3.02
1
2338 ACAR
88
2222 ZION - 2
ATC
345
345
0.87
1.94
2338 ACAR
89
2222 ZION - 3
ATC
345
345
1.87
2156 ACSR
90
2222 ZION - 4
ATC
345
345
0.15
2156 ACSR
91
2223 ZION - 1
ZION E.C.
345
345
0.15
1
2156 ACSR
92
2223 ZION - 2
ZION E.C.
345
345
3.04
2338 ACAR
93
2223 ZION - 3
ZION E.C.
345
345
2.79
2338 ACAR
94
2224 ZION - 1
LIBERTYVILLE
345
345
0.25
15.20
1
2338 ACAR
95
2224 ZION - 2
LIBERTYVILLE
345
345
0.87
1.92
2338 ACAR
96
2224 ZION - 3
LIBERTYVILLE
345
345
0.26
2156 ACSR
97
2310 COLLINS - 1
KENDALL CO.
345
345
0.20
1
2156 ACSR
98
2310 COLLINS - 2
KENDALL CO.
345
345
15.18
2156 ACSR
99
2311 COLLINS - 1
DRESDEN
345
345
0.56
1
2156 ACSR
100
2311 COLLINS - 2
DRESDEN
345
345
2.05
9.48
2156 ACSR
101
2912 JOLIET
LOCKPORT
345
345
12.71
1
2156 ACSR
102
2913 JOLIET
LOCKPORT
345
345
0.07
12.65
1
2156 ACSR
103
4620 DESPLAINES 46
PROSPECT HTS, 117
345
345
0.62
4.00
1
2156 ACSR
104
4621 DESPLAINES - 1
GOLF MILL
345
345
3.38
1
2156 ACSR
105
4621 DESPLAINES - 2
GOLF MILL
345
345
0.18
2156 ACSR
106
4622 DESPLAINES - 1
GOLF MILL
345
345
3.28
1
2156 ACSR
107
4622 DESPLAINES - 2
GOLF MILL
345
345
0.05
0.15
2156 ACSR
108
6607 EAST FRANKFORT - 1
CRETE E.C.
345
345
0.09
1
2156 ACSR
109
6607 EAST FRANKFORT - 2
CRETE E.C.
345
345
0.37
1414 PE ACSR
110
6607 EAST FRANKFORT - 3
CRETE E.C.
345
345
12.22
1414 PE ACSR
111
6608 EAST FRANKFORT - 1
UNIVERSITY PARK N.  E.C.
345
345
0.08
1
2156 ACSR
112
6608 EAST FRANKFORT - 2
UNIVERSITY PARK N.  E.C.
345
345
0.13
1414 ACSR
113
6608 EAST FRANKFORT - 3
UNIVERSITY PARK N.  E.C.
345
345
0.09
5.11
1414 ACSR
114
8001 PONTIAC MIDPOINT - 1
MCLEAN
345
345
10.33
1
2-1277 ACAR
115
8001 PONTIAC MIDPOINT - 2
MCLEAN
345
345
0.06
116
8002 PONTIAC MIDPOINT - 1
BLUE MOUND
345
345
20.13
1
2-1277ACAR
117
8002 PONTIAC MIDPOINT - 2
BLUE MOUND
345
345
7.22
2-1277ACAR
118
8012 PONTIAC MIDPOINT - 1
LORETTO
345
345
0.17
1
2-1277ACAR
119
8012 PONTIAC MIDPOINT - 2
LORETTO
345
345
11.32
2-1277ACAR
120
8014 DRESDEN
PONTIAC MIDPOINT
345
345
43.28
1
2-1277 ACAR
121
8823 SKOKIE 88 - 1
GOLF MILL
345
345
0.22
1
2156 ACSR
122
8823 SKOKIE 88 - 2
GOLF MILL
345
345
4.43
2156 ACSR
123
8824 SKOKIE 88 - 1
GOLF MILL
345
345
0.06
0.16
1
2156 ACSR
124
8824 SKOKIE 88 - 2
GOLF MILL
345
345
0.02
4.48
2156 ACSR
125
9203 MCLEAN - 1
BROKAW (AMEREN)
345
345
0.77
1
2-1277 ACAR
126
9203 MCLEAN - 2
BROKAW (AMEREN)
345
345
20.03
2-1277 ACAR
127
9503 CHESTNUT - 1
LATHAM (AMEREN)
345
345
5.83
1
2-1277 ACAR
128
9503 CHESTNUT - 2
LATHAM (AMEREN)
345
345
0.27
2-1277 ACAR
129
9515 CHESTNUT - 1
BLUEMOUND
345
345
34.74
1
2-1277 ACAR
130
9515 CHESTNUT - 2
BLUEMOUND
345
345
0.26
2-1277 ACAR
131
9806 NEVADA - 1
GOODINGS GROVE
345
345
0.17
0.39
1
2-1277 ACAR, 2156
132
9806 NEVADA - 2
GOODINGS GROVE
345
345
0.18
55.68
2-1277 ACAR, 2338
133
10111 ITASCA
DESPLAINES 46
345
345
9.01
1
2156 ACSR
134
10112 ITASCA
DESPLAINES 46
345
345
0.41
8.67
1
2156 ACSR
135
10321 LISLE
LOMBARD
345
345
8.68
1
2156 ACSR
136
10322 LISLE - 1
LOMBARD
345
345
0.38
8.47
1
2156 ACSR
137
10322 LISLE - 2
LOMBARD
345
345
0.17
2156 ACSR
138
10801 LOCKPORT
LOMBARD
345
345
12.69
1
2156 ACSR
139
10802 LOCKPORT - 1
LOMBARD
345
345
0.10
12.37
1
2156 ACSR
140
10802 LOCKPORT - 2
LOMBARD
345
345
0.17
2156 ACSR
141
10803 LOCKPORT - 1
MCCOOK
345
345
19.05
1
2338 ACAR,2156 ACSR
142
10803 LOCKPORT - 2
MCCOOK
345
345
0.43
2156 ACSR
143
10804 LOCKPORT - 1
MCCOOK
345
345
0.21
18.92
1
2338 ACAR,2156 ACSR
144
10804 LOCKPORT - 2
MCCOOK
345
345
0.43
2156 ACSR
145
10805 LOCKPORT - 1
KENDALL CO.
345
345
16.71
1
T2-1113 ACSR
146
10806 LOCKPORT - 1
KENDALL CO.
345
345
0.15
15.95
1
T2-1113 ACSR
147
10807 LOCKPORT
LOMBARD
345
345
21.53
1
T2-1113 ACSR
148
(b)
10808 LOCKPORT - 1
ITASCA
345
345
0.56
20.96
1
T2-1113 ACSR
149
10808 LOCKPORT - 2
ITASCA
345
345
8.05
2156 ACSR
150
11119 ELECTRIC JUNCTION
AURORA E.C.
345
345
0.43
1.00
1
2338 ACAR, 2156 ACSR
151
11120 ELECTRIC JUNCTION - 1
LOMBARD
345
345
4.41
1
2156 ACSR
152
11120 ELECTRIC JUNCTION - 2
LOMBARD
345
345
0.56
4.09
2338 ACAR
153
11120 ELECTRIC JUNCTION - 3
LOMBARD
345
345
8.93
2335 ACAR
154
11124 ELECTRIC JUNCTION - 1
LOMBARD
345
345
12.20
1
2335 ACAR
155
11124 ELECTRIC JUNCTION - 2
LOMBARD
345
345
0.84
2156 ACSR
156
11124 ELECTRIC JUNCTION - 3
LOMBARD
345
345
4.59
2338 ACAR
157
11126 ELECTRIC JUNCTION - 1
WAYNE
345
345
0.45
1
2156 ACSR, 2338 ACAR
158
11126 ELECTRIC JUNCTION - 2
WAYNE
345
345
13.33
2338 ACAR, 2156 ACSR
159
11212 WILTON CENTER - 1
LORETTO
345
345
1.95
1
2-1277 ACAR
160
11212 WILTON CENTER - 2
LORETTO
345
345
38.02
2-1277 ACAR
161
11601 GOODINGS GROVE - 1
EAST FRANKFORT
345
345
10.53
1
2-1033.5ACSS/TW
162
11601 GOODINGS GROVE - 2
EAST FRANKFORT
345
345
0.28
2-1033.5ACSS/TW
163
11602 GOODINGS GROVE - 1
EAST FRANKFORT
345
345
0.03
10.50
1
2-1033.5ACSS/TW
164
11602 GOODINGS GROVE - 2
EAST FRANKFORT
345
345
0.23
2-1033.5ACSS/TW
165
11604 GOODINGS GROVE
LOCKPORT
345
345
9.02
1
2156 ACSR
166
11607 GOODINGS GROVE
BEDFORD PARK
345
345
18.51
1
2156 ACSR
167
11608 GOODINGS GROVE
BEDFORD PARK
345
345
0.15
18.43
1
2156 ACSR
168
11613 TAP
BLUE ISLAND
345
345
0.05
7.59
1
2338 ACAR
169
11613 GOODINGS GROVE - 1
WILTON CENTER
345
345
0.58
0.14
2156 ACSR, 2338 ACAR
170
11613 GOODINGS GROVE - 2
WILTON CENTER
345
345
9.63
21.09
2338 ACAR
171
11614 GOODINGS GROVE - 1
WILTON CENTER
345
345
30.60
1
2338 ACAR, 2-1277 ACAR
172
11614 GOODINGS GROVE - 2
WILTON CENTER
345
345
0.70
2338 ACAR, 2156 ACSR
173
11614 TAP
BLUE ISLAND
345
345
7.64
2338 ACAR
174
11617 GOODINGS GROVE - 1
LOCKPORT
345
345
0.08
8.80
1
2156 ACSR
175
11617 GOODINGS GROVE - 2
LOCKPORT
345
345
0.03
0.08
2156 ACSR
176
11620 GOODINGS GROVE - 1
ELWOOD
345
345
0.33
17.50
1
2156 ACSR
177
11620 GOODINGS GROVE - 2
ELWOOD
345
345
0.36
0.52
2156/T2-1113 ACSR
178
11622 GOODINGS GROVE - 1
ELWOOD
345
345
17.85
1
2156 ACSR
179
11622 GOODINGS GROVE - 2
ELWOOD
345
345
0.86
T2-1113,2156 ACSR
180
11723 PROSPECT HTS. 117
LIBERTYVILLE
345
345
15.36
1
2156 ACSR
181
11724 PROSPECT HTS. 117
DES PLAINES TSS46
345
345
4.57
1
2338 ACAR, 2156 ACSR
182
12002 LOMBARD
ITASCA
345
345
0.22
7.95
1
2156 ACSR
183
12003 LOMBARD
ELMHURST
345
345
7.98
1
2338 ACAR, 2-664.8 ACSS/TW
184
12004 LOMBARD
ELMHURST
345
345
0.15
7.77
1
2156 ACSR, 2338 ACAR, 2-664.8 ACSS/TW
185
12005 LOMBARD
DESPLAINES
345
345
0.32
16.78
1
2156 ACSR
186
12006 LOMBARD
DESPLAINES
345
345
17.09
1
2156 ACSR
187
13817 SILVER LAKE - 1
PLEASANT VALLEY
345
345
9.35
1
2156 ACSR
188
13817 SILVER LAKE - 2
PLEASANT VALLEY
345
345
0.39
2156 ACSR
189
13821 SILVER LAKE - 1
LIBERTYVILLE
345
345
0.59
16.89
1
2338 ACAR
190
13821 SILVER LAKE - 2
LIBERTYVILLE
345
345
0.19
2156 ACSR
191
14321 WOLFS - 1
ELECTRIC JUNCTION
345
345
6.29
1
2156 ACSR, 2338 ACAR
192
14321 WOLFS - 2
ELECTRIC JUNCTION
345
345
0.19
2156 ACSR
193
14401 WAYNE - 1
SILVER LAKE
345
345
0.24
19.41
1
2338 ACAR
194
14401 WAYNE - 2
SILVER LAKE
345
345
0.11
0.29
2338 ACAR
195
14402 WAYNE - 1
TOLLWAY
345
345
5.54
1
2338 ACAR, 2156 ACSR
196
14402 WAYNE - 2
TOLLWAY
345
345
0.06
2156 ACSR
197
14419 WAYNE - 1
AURORA E.C.
345
345
0.03
12.34
1
2338 ACAR
198
14419 WAYNE - 2
AURORA E.C.
345
345
0.16
2156 ACSR, 2338 ACAR
199
15324 TAYLOR
FISK
345
345
0.20
1
2156 ACSR
200
15423 LIBERTYVILLE - 1
ZION E.C.
345
345
12.33
1
2156 ACSR
201
15423 LIBERTYVILLE - 2
ZION E.C.
345
345
0.11
2156 ACSR
202
15424 LIBERTYVILLE
PROSPECT HTS, 117
345
345
0.34
14.93
1
2338 ACAR, 2156 ACSR
203
15501 NELSON - 1
LEE COUNTY E.C.
345
345
4.29
1
2338 ACAR
204
15501 NELSON - 2
LEE COUNTY E.C.
345
345
8.63
2-1277 ACAR
205
15501 NELSON - 3
LEE COUNTY E.C.
345
345
0.07
2-1277 ACAR
206
15502 NELSON - 1
ELECTRIC JUNCTION
345
345
15.92
1
2-1033.5 ACSS/TW
207
15502 NELSON - 2
ELECTRIC JUNCTION
345
345
4.65
2-1277 ACAR
208
15502 NELSON - 3
ELECTRIC JUNCTION
345
345
52.61
2-1277 ACAR
209
15503 NELSON - 1
CORDOVA
345
345
0.07
0.34
1
2-1033.5 ACSS/TW,
210
15503 NELSON - 2
CORDOVA
345
345
39.23
2-1227 ACAR
211
15503 NELSON - 3
CORDOVA
345
345
0.04
2-1277 ACAR
212
15504 NELSON
N.W. STEEL & WIRE
345
345
5.76
2.15
1
2-1277 ACAR
213
15615 CHERRY VALLEY
WEMPLETOWN
345
345
27.22
1
2156 ACSR
214
15616 CHERRY VALLEY - 1
SILVER LAKE
345
345
39.55
1
2338 ACAR, 2156 ACSR
215
15616 CHERRY VALLEY - 2
SILVER LAKE
345
345
0.98
T2-1113 ACSR
216
15925 NORTHBROOK
SKOKIE 88
345
345
5.63
1
2156 ACSR
217
15926 NORTHBROOK
SKOKIE 88
345
345
0.06
5.46
1
2156 ACSR
218
16703 PLANO - 1
ELECTRIC JUNCTION
345
345
0.12
11.48
1
2156 ACSR
219
16703 PLANO - 2
ELECTRIC JUNCTION
345
345
9.59
2156 ACSR
220
16704 PLANO - 1
ELECTRIC JUNCTION
345
345
11.60
1
2156 ACSR
221
16704 PLANO - 2
ELECTRIC JUNCTION
345
345
9.66
2156 ACSR
222
17101 WEMPLETOWN - 1
ATC INTERCONNECTION
345
345
10.40
1
2156 ACSR
223
17101 WEMPLETOWN - 2
ATC INTERCONNECTION
345
345
0.99
2156 ACSR
224
17102 WEMPLETOWN - 1
ATC INTERCONNECTION
345
345
0.06
10.34
1
2156 ACSR
225
17102 WEMPLETOWN - 2
ATC INTERCONNECTION
345
345
0.99
2156 ACSR
226
17701 BURNHAM - 1
BLUE ISLAND
345
345
7.79
1
2338 ACAR
227
17701 BURNHAM - 2
BLUE ISLAND
345
345
0.60
2156 ACSR
228
17702 BURNHAM
BLUE ISLAND
345
345
0.10
8.13
1
2338 ACAR
229
17703 BURNHAM
NIPSCO
345
345
8.51
1
2338 ACAR
230
17704 BURNHAM - 1
DAVIS CREEK
345
345
17.49
1
2156 ACSR, T2-1113 ACSR, 2338 ACAR
231
17704 BURNHAM - 2
DAVIS CREEK
345
345
32.36
2156 ACSR, T2-1113 ACSR
232
17705 BURNHAM
SHEFFIELD (NIPSCO)
345
345
0.04
3.68
1
2338 ACAR
233
17723 BURNHAM - 1
STATE LINE
345
345
0.05
1
2156 ACSR
234
17723 BURNHAM - 2
STATE LINE
345
345
3.80
2156 ACSR
235
17723 STATE LINE - 1
TAYLOR
345
345
8.84
2156 ACSR, 2-1277 ACAR
236
17723 STATE LINE - 2
TAYLOR
345
345
0.13
2156 ACSR
237
17724 BURNHAM
STATE LINE
345
345
0.20
3.71
1
2156 ACSR
238
17724 STATE LINE - 1
TAYLOR
345
345
0.50
8.47
2156 ACSR, 2-1277 ACAR
239
17724 STATE LINE - 2
TAYLOR
345
345
0.13
2156 ACSR
240
17907 DAVIS CREEK - 1
BLOOM
345
345
0.14
8.22
1
2156 ACSR
241
17907 DAVIS CREEK - 2
BLOOM
345
345
24.00
T2-1113 ACSR
242
17907 DAVIS CREEK - 3
BLOOM
345
345
0.17
4.73
2156 ACSR
243
17907 DAVIS CREEK - 4
BLOOM
345
345
0.06
0.17
T2-1113 ACSR
244
17908 BURNHAM
BLOOM
345
345
0.25
12.17
1
2156 ACSR, 2338 ACAR
245
18502 TOLLWAY - 1
LIBERTYVILLE
345
345
22.84
1
2338 ACAR
246
18502 TOLLWAY - 2
LIBERTYVILLE
345
345
7.69
2156 ACSR
247
18502 TOLLWAY - 3
LIBERTYVILLE
345
345
0.12
2338 ACAR
248
18502 TOLLWAY - 4
LIBERTYVILLE
345
345
0.12
2156 ACSR
249
18806 MT. PULASKI - 1
DEER CREEK
345
345
0.73
1
2-1277 ACAR
250
18806 MT. PULASKI - 2
DEER CREEK
345
345
15.82
2-1277 ACAR
251
18806 MT. PULASKI - 3
DEER CREEK
345
345
1.09
2-1277 ACAR
252
19601 KATYDID - 1
GOODINGS GROVE
345
345
0.06
1
2-1277 ACAR, 2156
253
19601 KATYDID - 2
GOODINGS GROVE
345
345
53.45
2-1277 ACAR, 2156
254
90907 DEER CREEK - 1
BROKAW (AMEREN)
345
345
7.49
1
2-1277 ACAR
255
90907 DEER CREEK - 2
BROKAW (AMEREN)
345
345
13.04
2-1277 ACAR
256
90907 DEER CREEK - 3
BROKAW (AMEREN)
345
345
1.27
2-1277 ACAR
257
93505 KENDALL CO. - 1
DRESDEN
345
345
0.38
1
2338 ACAR, 2156 A
258
93505 KENDALL CO. - 2
DRESDEN
345
345
7.38
2338 ACAR, 2-1277
259
93913 MULBERRY - 1
MOLE CREEK
345
345
0.47
1
2-1277 ACAR, 2156 ACSR
260
93913 MULBERRY - 2
MOLE CREEK
345
345
57.28
2-1277 ACAR, 2338 ACAR
261
93915 MULBERRY - 1
TAZEWELL (CLICO)
345
345
0.16
0.18
1
2156 ACSR
262
93915 MULBERRY - 2
TAZEWELL (CLICO)
345
345
0.17
94.27
2-1277 ACAR, 2338 ACAR
263
97008 UNIVERSITY PK.  E.C. - 1
I & M POWER
345
345
4.57
7.03
1
1414 ACSR
264
97008 UNIVERSITY PK.  E.C. - 2
I & M POWER
345
345
0.62
1414 ACSR, 2156 A
265
94507 CRETE E.C. - 1
N.I.P.S.CO.
345
345
4.54
1
1414 ACSR, 2156 A
266
94507 CRETE E.C. - 2
N.I.P.S.CO.
345
345
0.42
1414 ACSR, 2156 A
267
345KV LINES
268
1309 FISK TERMINAL
WEST LOOP
345
345
4.87
1600mm2 XLPE
269
15323 TAYLOR
WEST LOOP
345
345
3.30
1
1600mm2 XLPE
270
15324 TAYLOR
FISK
345
345
2.20
1600mm2 XLPE
271
17723X TAYLOR
GARFIELD
345
345
6.08
2500KCMIL
272
17724Y TAYLOR - 1
GARFIELD
345
345
6.08
2500KCMIL
273
17724X TAYLOR
GARFIELD
345
345
6.11
1600mm2 XLPE
274
17724Y TAYLOR - 2
GARFIELD
345
345
6.10
1600mm2 XLPE
275
138KV LINES OVERHEAD
276
2 STEAM PLANT ROAD - 1
TWOMBLY ROAD
138
138
2.63
1
556.5 ACSR
277
2 STEAM PLANT ROAD - 2
TWOMBLY ROAD
138
138
0.47
556.5 ACSR
278
4 STEAM PLANT ROAD
CARON ROAD
138
138
0.06
1
556.5 ACSR
279
0108 LASALLE CO. - 1
SW TIE L-1205
138
138
0.37
1
1113 ACSR, 664.8 ACSS/TW
280
0108 LASALLE CO. - 2
SW TIE L-1205
138
138
2.95
664.8 ACSS, 477&1
281
0108 LASALLE CO. - 3
SW TIE L-1205
138
138
0.30
664.8 ACSS/TW
282
0108 LASALLE CO. - 4
SW TIE L-1205
138
138
12.89
300CU,477ACS
283
0108 TAP
SW TIE L-6102
138
138
0.06
477 ACSR
284
0112 LASALLE CO.
KICKAPOO CREEK
138
138
1.35
1113 ACSR, T2-555
285
0321 POWERTON - 1
TOULON
138
138
42.21
1
477,1113 ACSR
286
0321 POWERTON - 2
TOULON
138
138
0.65
1113 ACSR, 922
287
0703 STATE LINE
HEGEWISCH
138
138
0.26
2.39
1
1113 ACSR
288
0703 TAP - 1
LTV STEEL
138
138
0.07
477ACSR
289
0703 TAP - 2
RIVER E.C.
138
138
0.39
477,636, 2-336.4A
290
0703 TAP - 3
RIVER E.C.
138
138
1.87
477,636,
291
0704 STATE LINE - 1
RIVER E.C.
138
138
1.15
1
336.4,477,636,111
292
0704 STATE LINE - 2
RIVER E.C.
138
138
0.21
1.79
636, 1113ACSR
293
0704 STATE LINE - 3
RIVER E.C.
138
138
0.16
1113 ACSR
294
0704 TAP - 1
TOWER AUTOMOTIVE
138
138
0.10
0.16
1113 ACSR
295
0704 TAP - 2
TOWER AUTOMOTIVE
138
138
0.11
1113 ACSR
296
0706 STATE LINE - 1
CALUMET
138
138
1.28
1
1113,2156 ACSR
297
0706 STATE LINE - 2
CALUMET
138
138
0.10
1113,2156 ACSR
298
0706 STATE LINE - 3
CALUMET
138
138
0.07
1113 ACSR
299
0707 STATE LINE - 1
CALUMET
138
138
0.59
1
750 CU / 1113,215
300
0707 STATE LINE - 2
CALUMET
138
138
1.10
2156 ACSR
301
0707 TAP
TAP TO T-3030
138
138
0.18
2156 ACSR
302
0708 STATE LINE - 1
CALUMET
138
138
0.24
0.61
1
750 CU / 1113,215
303
0708 STATE LINE - 2
CALUMET
138
138
0.12
0.99
2156 ACSR
304
0708 TAP - 1
HARBOR
138
138
0.08
2156 ACSR
305
0708 TAP - 2
HARBOR
138
138
0.21
2156 ACSR
306
0716 ILL-IND STATE LINE - 1
CALUMET
138
138
0.09
1
1113 ACSR
307
0716 ILL-IND STATE LINE - 2
CALUMET
138
138
0.24
1.07
2-1277.2 ACAR / 1
308
0716 ILL-IND STATE LINE - 3
CALUMET
138
138
0.13
2156 ACSR
309
0901 JOLIET - 1
EAST FRANKFORT
138
138
14.75
1
300CU/636,1113/66
310
0901 JOLIET - 2
EAST FRANKFORT
138
138
0.08
0.30
300 CU
311
0901 TAP - 1
DAVIS CREEK
138
138
19.52
2-556.5,1113 ACSR
312
0901 TAP - 2
DAVIS CREEK
138
138
0.17
2-556.5 ACSR
313
0901 TAP - 3
DAVIS CREEK
138
138
0.76
1113 ACSR
314
0901 TAP - 4
DAVIS CREEK
138
138
0.06
0.47
1113 ACSR
315
0902 JOLIET - 1
EAST FRANKFORT
138
138
3.83
11.24
1
477,1113 ACSR, 66
316
0902 JOLIET - 2
EAST FRANKFORT
138
138
0.09
477 ACSR
317
0902 TAP - 1
DAVIS CREEK
138
138
10.69
636 ACSR
318
0902 TAP - 2
DAVIS CREEK
138
138
8.70
636 ACSR
319
0902 TAP - 3
DAVIS CREEK
138
138
0.19
2.41
636,1113 ACSR
320
0902 TAP - 4
DAVIS CREEK
138
138
0.06
0.63
1113 ACSR
321
0903 JOLIET - 1
DRESDEN
138
138
0.24
7.67
1
1113 ACSR
322
0903 JOLIET - 2
DRESDEN
138
138
0.49
6.94
1113 ACSR
323
0904 JOLIET - 1
DRESDEN
138
138
0.33
9.22
1
300 CU / 1113 ACS
324
0904 JOLIET - 2
DRESDEN
138
138
0.58
1113 ACSR
325
0904 JOLIET - 3
DRESDEN
138
138
4.87
0.08
1113 ACSR
326
0905 JOLIET - 1
WILL COUNTY
138
138
5.20
7.08
1
477, T2-556.5 ACSR, 763.0 ACCR/TW
327
0905 JOLIET - 2
WILL COUNTY
138
138
2.65
T2-556.5 ACSR, 664.8 ACSS/TW
328
0905 TAP
JOLIET TR.# 79
138
138
0.01
477 ACSR
329
0906 JOLIET - 1
WILL COUNTY
138
138
7.86
7.88
1
477, 900, 1113, T2-556.5 ACSR, 664.8 ACSS/TW
330
0906 JOLIET - 2
WILL COUNTY
138
138
0.82
T2-556.5 ACSR, 664.8 ACSS/TW
331
0907 JOLIET - 1
WOLFS
138
138
2.85
15.60
1
300 CU / 1113 ACW
332
0907 JOLIET - 2
WOLFS
138
138
0.08
1113 ACSR
333
0907 JOLIET - 3
WOLFS
138
138
0.06
300 CU
334
0908 JOLIET - 1
SHOREWOOD
138
138
0.34
7.79
1
1113 ACSR
335
0908 JOLIET - 2
SHOREWOOD
138
138
0.08
1113 ACSR
336
0908 JOLIET - 3
SHOREWOOD
138
138
0.13
5.64
1113 ACSR
337
1106 FISK
QUARRY
138
138
0.21
1
1113 ACSR
338
1108 FISK
QUARRY
138
138
0.17
1
1113ACSR
339
1205 DRESDEN - 1
SW TIE L-0108
138
138
8.30
8.20
1
300 CU / 477,1113
340
1205 DRESDEN - 2
SW TIE L-0108
138
138
0.07
477,1113 ACSR
341
1205 TAP
MAZON
138
138
0.09
477 ACSR
342
1206 DRESDEN - 1
CHANNAHON WEST
138
138
2.55
3.75
477,1113 ACSR
343
1206 DRESDEN - 2
CHANNAHON WEST
138
138
0.28
1113 ACSR
344
1206 TAP
EQUISTAR
138
138
0.11
0.09
345
1207 DRESDEN - 1
WILMINGTON
138
138
13.05
1
636 ACSR
346
1207 DRESDEN - 2
WILMINGTON
138
138
0.14
636 ACSR
347
1210 DRESDEN - 1
CARGO COURT
138
138
2.00
1
1113 AA / 1113 AC
348
1210 DRESDEN -2
CARGO COURT
138
138
2.94
1113 AA / 1113 AC
349
1306 RIDGELAND - 1
CRAWFORD
138
138
0.05
0.73
1
1113 ACSR
350
1306 RIDGELAND - 2
CRAWFORD
138
138
0.36
2.50
1113 ACSR
351
1315 RIDGELAND - 1
CRAWFORD
138
138
0.16
1.20
1
900, 1113 ACSR
352
1315 RIDGELAND - 2
CRAWFORD
138
138
0.27
2.66
1113 ACSR
353
1315 RIDGELAND - 3
CRAWFORD
138
138
0.03
900 ACSR
354
1321 CRAWFORD - 1
CONGRESS
138
138
0.31
0.40
1
1113 ACSR
355
1321 CRAWFORD - 2
CONGRESS
138
138
0.28
4.02
1113 ACSR
356
1322 CRAWFORD - 1
BEDFORD PARK
138
138
0.29
3.13
1
1113 ACSR
357
1322 CRAWFORD - 2
BEDFORD PARK
138
138
0.02
4.31
2-556.5,1113 ACSR
358
1322 CRAWFORD - 3
BEDFORD PARK
138
138
0.05
1113 ACSR
359
1323 CRAWFORD - 1
CONGRESS
138
138
0.67
1
1113 ACSR
360
1323 CRAWFORD - 2
CONGRESS
138
138
4.44
1113 ACSR
361
1324 CRAWFORD - 1
BEDFORD PARK
138
138
0.28
2.82
1
1113 ACSR
362
1324 CRAWFORD - 2
BEDFORD PARK
138
138
0.02
4.26
2-556.5,1113 ACSR
363
1324 CRAWFORD - 3
BEDFORD PARK
138
138
0.41
1113 ACSR
364
1404 POWERTON
JUNCTION WITH AMEREN
138
138
0.37
477 ACSR
365
1603 WAUKEGAN - 1
SW TIE L-4203
138
138
0.28
14.55
1
300 CU / 477,1113
366
1603 WAUKEGAN - 2
SW TIE L-4203
138
138
0.32
0.34
300 CU / 477,1113
367
1604 WAUKEGAN - 1
LIBERTYVILLE
138
138
0.24
13.45
1
1113 ACSR
368
1604 WAUKEGAN - 2
LIBERTYVILLE
138
138
0.10
0.50
1113 ACSR
369
1604 WAUKEGAN - 3
LIBERTYVILLE
138
138
0.05
1113 ACSR
370
1605 WAUKEGAN - 1
HIGHLAND PARK
138
138
15.80
1
1113 ACSR
371
1605 WAUKEGAN - 2
HIGHLAND PARK
138
138
0.35
1113 ACSR
372
1605 WAUKEGAN - 3
HIGHLAND PARK
138
138
0.98
1113,2156 ACSR
373
1606 WAUKEGAN - 1
HIGHLAND PARK
138
138
0.10
15.80
1
1113 ACSR
374
1606 WAUKEGAN - 2
HIGHLAND PARK
138
138
0.30
1113 ACSR
375
1606 WAUKEGAN - 3
HIGHLAND PARK
138
138
0.53
0.48
1113,2156 ACSR
376
1607 WAUKEGAN - 1
SW TIE L-4202
138
138
0.32
14.76
1
300CU/1113ACSR/
377
1607 WAUKEGAN - 2
SW TIE L-4202
138
138
0.19
0.34
300CU/1113ACSR/
378
1607 TAP
ROUND LAKE
138
138
0.03
477 ACSR
379
1608 WAUKEGAN - 1
LIBERTYVILLE
138
138
0.23
13.47
1
1113 ACSR
380
1608 WAUKEGAN - 2
LIBERTYVILLE
138
138
0.09
0.50
1113 ACSR
381
1608 WAUKEGAN - 3
LIBERTYVILLE
138
138
0.05
1113 ACSR
382
1609 WAUKEGAN - 1
ZION TDC 282
138
138
5.54
1
1113 ACSR
383
1609 WAUKEGAN - 2
ZION TDC 282
138
138
0.15
900,1113 ACSR
384
1609 WAUKEGAN - 3
ZION TDC 282
138
138
4.41
1.79
1113 ACSR
385
1609 WAUKEGAN - 4
ZION TDC 282
138
138
0.31
1113 ACSR
386
1802 WILL COUNTY - 1
ARGONNE
138
138
0.45
7.08
1
1113 ACSR
387
1802 WILL COUNTY - 2
ARGONNE
138
138
0.28
0.43
1113 ACSR
388
1802 WILL COUNTY - 3
ARGONNE
138
138
0.07
1113 ACSR
389
1803 WILL COUNTY - 1
BOLINGBROOK BREAKER
138
138
2.50
1
2-556.5 ACSR
390
1803 WILL COUNTY - 2
BOLINGBROOK BREAKER
138
138
4.00
2-556.5,1113 ACSR
391
1804 WILL COUNTY - 1
WOLFS
138
138
5.44
9.07
1
477,900,1113
392
1804 WILL COUNTY - 2
WOLFS
138
138
0.08
1113 ACSR
393
1807 WILL COUNTY - 1
ARGONNE NAT'L LAB
138
138
0.50
7.07
1
1113 ACSR
394
1807 WILL COUNTY - 2
ARGONNE NAT'L LAB
138
138
0.04
1113 ACSR
395
1807 WILL COUNTY - 3
ARGONNE NAT'L LAB
138
138
0.43
1113 ACSR
396
1808 WILL COUNTY - 1
GOODINGS GROVE
138
138
0.57
8.92
1
900 ACSR
397
1808 WILL COUNTY - 2
GOODINGS GROVE
138
138
0.13
0.55
900 ACSR
398
1809 WILL COUNTY - 1
NORMANTOWN
138
138
0.47
0.94
1
1033.5ACSS/TW, 2-
399
1809 WILL COUNTY - 2
NORMANTOWN
138
138
0.03
2.22
2-566.5, 2156ACSR
400
1811 WILL COUNTY - 1
GOODINGS GROVE
138
138
0.91
8.49
1
900 ACSR
401
1811 WILL COUNTY - 2
GOODINGS GROVE
138
138
0.60
900 ACSR
402
4202 SILVER LAKE - 1
SW TIE L-1607
138
138
0.37
13.68
1
300 CU / 477,1113
403
4202 SILVER LAKE - 2
SW TIE L-1607
138
138
0.14
0.13
1113 ACSR
404
4203 SILVER LAKE - 1
SW TIE L-1603
138
138
10.00
4.00
1
477,1113 ACSR
405
4203 SILVER LAKE - 2
SW TIE L-1603
138
138
0.18
0.13
477 ACSR
406
4203 SILVER LAKE - 3
SW TIE L-1603
138
138
0.07
1113 ACSR
407
4203 TAP
ROUND LAKE
138
138
0.05
1113 ACSR
408
4605 DESPLAINES 46 - 1
ELK GROVE
138
138
0.17
4.14
1
1113 ACSR
409
4605 DESPLAINES 46 - 2
ELK GROVE
138
138
0.20
1113,2156 ACSR
410
4609 DESPLAINES 46 - 1
DESPLAINES 198
138
138
0.12
3.06
1
1113 ACSR, 664.8
411
4609 DESPLAINES 46 - 2
DESPLAINES 198
138
138
0.23
1113 ACSR
412
4606 DESPLAINES 46 - 1
ELK GROVE
138
138
4.08
1
1113 ACSR
413
4606 DESPLAINES 46 - 2
ELK GROVE
138
138
0.38
1113 ACSR
414
4608 DESPLAINES 46 - 1
DESPLAINES 198
138
138
0.32
3.03
1
1113 ACSR, 664.8
415
4608 DESPLAINES 46 - 2
DESPLAINES 198
138
138
0.07
1113 ACSR
416
4608 DESPLAINES 46 - 3
DESPLAINES 198
138
138
0.10
1113 ACSR
417
4610 DESPLAINES 46 - 1
GOLF MILL
138
138
0.06
3.46
1
1113 ACSR
418
4610 DESPLAINES 46 - 2
GOLF MILL
138
138
0.05
1113 ACSR
419
4610 DESPLAINES 46 - 3
GOLF MILL
138
138
0.16
1113 ACSR
420
4611 DESPLAINES 46 - 1
GOLF MILL
138
138
3.47
1
1113 ACSR
421
4611 DESPLAINES 46 - 2
GOLF MILL
138
138
0.04
1113 ACSR
422
4611 DESPLAINES 46 - 3
GOLF MILL
138
138
0.30
1113 ACSR
423
5103 MCCOOK - 1
WILLOW SPRINGS
138
138
0.42
4.86
1
1113 ACSR
424
5103 MCCOOK - 2
WILLOW SPRINGS
138
138
0.09
1113 ACSR
425
5103 MCCOOK - 3
WILLOW SPRINGS
138
138
0.09
1113 ACSR
426
5103 TAP - 1
BEDFORD PARK
138
138
0.96
1113 ACSR
427
5103 TAP - 2
BEDFORD PARK
138
138
4.20
477,1113 ACSR
428
5104 MCCOOK - 1
BEDFORD PARK
138
138
2.50
1
900,1113 ACSR, 10
429
5104 MCCOOK - 2
BEDFORD PARK
138
138
1.06
0.96
1113 ACSR, 1033.5
430
5104 MCCOOK - 3
BEDFORD PARK
138
138
1.94
900 ACSR
431
5104 MCCOOK - 4
BEDFORD PARK
138
138
1.10
900 ACSR
432
5104 TAP - 1
ARGONNE LABS
138
138
8.33
900 ACSR
433
5104 TAP - 2
ARGONNE LABS
138
138
0.10
1113 ACSR
434
5105 RIDGELAND
MCCOOK
138
138
0.33
1.78
1
900,1113 ACSR
435
5107 MCCOOK - 1
RIDGELAND
138
138
0.40
1.80
1
1033.5ACSS/TW, 2-
436
5107 MCCOOK - 2
RIDGELAND
138
138
0.20
1033.5 ACSS/TW
437
5117 MCCOOK - 1
BELLWOOD
138
138
6.78
1
1113 AA / 1113 AC
438
5117 MCCOOK - 2
BELLWOOD
138
138
1.38
1113 AA / 1113 AC
439
5118 MCCOOK - 1
BELLWOOD
138
138
0.02
6.33
1
1113 AA / 1113 AC
440
5118 MCCOOK - 2
BELLWOOD
138
138
0.12
1.60
1113 AA / 1113 AC
441
6101 STREATOR - 1
PUTNAM (AMEREN)
138
138
29.62
1
300 CU / 300,477 ACSR
442
6101 STREATOR - 2
PUTNAM (AMEREN)
138
138
0.94
477, 2-556.5 ACSR
443
6102 STREATOR - 1
KICKAPOO CREEK
138
138
0.11
9.34
1
477 ACSR, 664.8 ACSS/TW
444
6102 STREATOR - 2
KICKAPOO CREEK
138
138
2.07
636 ACSR, 477
445
6102 STREATOR - 3
KICKAPOO CREEK
138
138
11.37
477 ACSR
446
6102 STREATOR - 4
KICKAPOO CREEK
138
138
0.01
1113 KCMIL
447
6102 TAP
MARSEILLES S.S.
138
138
0.01
477 ACSR
448
6603 EAST FRANKFORT - 1
MATTESON
138
138
0.10
5.36
1
300 CU / 477,1113
449
6603 EAST FRANKFORT - 2
MATTESON
138
138
0.54
1113 ACSR,664.8 A
450
6603 EAST FRANKFORT - 3
MATTESON
138
138
0.07
1113 ACSR
451
6604 EAST FRANKFORT - 1
MATTESON
138
138
0.03
5.82
1
477, 664.8 ACSS/T
452
6604 EAST FRANKFORT - 2
MATTESON
138
138
0.13
1113 ACSR
453
6604 EAST FRANKFORT - 3
MATTESON
138
138
0.11
1113 ACSR
454
6605 EAST FRANKFORT - 1
UNIVERSITY PARK
138
138
0.05
1
1113 ACSR
455
6605 EAST FRANKFORT - 2
UNIVERSITY PARK
138
138
5.34
1113 ACSR
456
6606 EAST FRANKFORT - 1
UNIVERSITY PARK
138
138
5.34
1
1113 ACSR
457
6606 EAST FRANKFORT - 2
UNIVERSITY PARK
138
138
0.04
1113 ACSR
458
6721 CONGRESS - 1
ROCKWELL
138
138
0.01
0.25
1
1113 ACSR
459
6721 CONGRESS - 2
ROCKWELL
138
138
0.01
0.94
1113 ACSR
460
6721 CONGRESS - 3
ROCKWELL
138
138
0.08
1113 ACSR
461
6723 CONGRESS - 1
ROCKWELL
138
138
0.03
0.36
1
1113 ACSR
462
6723 CONGRESS - 2
ROCKWELL
138
138
0.91
1113 ACSR
463
7305 CHICAGO HTS. - 1
BLOOM
138
138
0.11
1
1113 ACSR
464
7305 CHICAGO HTS. - 2
BLOOM
138
138
0.32
1113 ACSR
465
7305 CHICAGO HTS. - 3
BLOOM
138
138
0.75
1.29
1113 ACSR
466
7306 CHICAGO HTS. - 1
BLOOM
138
138
0.05
1
1113 ACSR
467
7306 CHICAGO HTS. - 2
BLOOM
138
138
2.19
1113 ACSR
468
7306 CHICAGO HTS. - 3
BLOOM
138
138
0.24
1113 ACSR
469
7307 CHICAGO HTS. - 1
BURNHAM
138
138
1.41
4.39
1
1113,2338 ACSR
470
7307 CHICAGO HTS. - 2
BURNHAM
138
138
0.15
0.18
1113 ACSR
471
7307 CHICAGO HTS. - 3
BURNHAM
138
138
3.74
1113 ACSR
472
7411 KEWANEE
AMEREN KEEMIN
138
138
6.91
1
477 ACSR
473
7413 KEWANEE - 1
CRESCENT RIDGE
138
138
0.18
15.23
1
300 CU / 477 ACSR
474
7413 KEWANEE - 2
CRESCENT RIDGE
138
138
0.02
1113 ACSR
475
7421 KEWANEE - 1
TOULON
138
138
11.70
1
477 ACSR
476
7421 KEWANEE - 2
TOULON
138
138
0.04
1113 ACSR
477
7423 KEWANEE - 1
EDWARD STA (CILCO)
138
138
0.18
50.04
1
477 ACSR
478
7423 KEWANEE - 2
EDWARD STA (CILCO)
138
138
0.47
0.01
1113 ACSR
479
7611 BLUE ISLAND - 1
WILDWOOD
138
138
0.13
3.81
1
900 ACSR
480
7611 BLUE ISLAND - 2
WILDWOOD
138
138
0.13
900 ACSR
481
7612 BLUE ISLAND - 1
WILDWOOD
138
138
0.20
3.74
1
900,1113 ACSR
482
7612 BLUE ISLAND - 2
WILDWOOD
138
138
0.01
0.13
900 ACSR
483
7615 BLUE ISLAND - 1
SW TIE L-11603
138
138
3.44
0.36
1
1113 ACSR
484
7616 BLUE ISLAND - 2
SW TIE L-11609
138
138
0.34
3.43
1
1113 ACSR
485
7713 MAZON - 1
CORBIN (AMEREN)
138
138
34.42
0.00
1
300 CU, 477 ACSR
486
7713 MAZON - 2
CORBIN (AMEREN)
138
138
0.15
0.00
1113 ACSR
487
7719 MAZON - 1
CHANNAHON WEST
138
138
5.73
4.29
1
3000 CU/1113
488
7719 MAZON - 2
CHANNAHON WEST
138
138
0.07
1113 ACSR
489
7719 MAZON - 3
CHANNAHON WEST
138
138
0.07
266.5 ACSR
490
7719 TAP
SW TIE L-7413
138
138
0.07
300 CU
491
7902 SPAULDING - 1
TOLLWAY
138
138
0.22
3.79
1
1113,2156 ACSR
492
7902 SPAULDING - 2
TOLLWAY
138
138
0.03
0.15
2156 ACSR
493
7903 SPAULDING - 1
TOLLWAY
138
138
0.13
3.79
1
1113,2156 ACSR
494
7903 SPAULDING - 2
TOLLWAY
138
138
0.10
0.15
1113 ACSR
495
7903 SPAULDING - 3
TOLLWAY
138
138
0.09
1113 ACSR
496
7910 SPAULDING - 1
WAYNE
138
138
0.08
1.23
1
1113 ACSR
497
7910 SPAULDING - 2
WAYNE
138
138
0.16
1113,2156 ACSR
498
7910 SPAULDING - 3
WAYNE
138
138
0.25
1113 ACSR
499
7915 SPAULDING - 1
WAYNE
138
138
0.44
1
1113,2156 ACSR
500
7915 SPAULDING - 2
WAYNE
138
138
0.02
1.19
1113 ACSR
501
8221 CROSBY - 1
ROCKWELL
138
138
0.08
1.53
1
1113 ACSR
502
8221 CROSBY - 2
ROCKWELL
138
138
0.01
0.29
1113 ACSR
503
8223 CROSBY - 1
ROCKWELL
138
138
0.08
1.51
1
1113 ACSR
504
8223 CROSBY - 2
ROCKWELL
138
138
0.02
0.29
1113 ACSR
505
8607 DAVIS CREEK - 1
WILMINGTON
138
138
0.14
1.83
1
1113 ACSR
506
8607 DAVIS CREEK - 2
WILMINGTON
138
138
0.68
1113 ACSR
507
8607 DAVIS CREEK - 3
WILMINGTON
138
138
21.58
0.24
636 ACSR, 113 ACSR
508
8801 SKOKIE 88 - 1
GOLF MILL
138
138
4.41
1
1113 ACSR
509
8801 SKOKIE 88 - 2
GOLF MILL
138
138
0.03
1113 ACSR
510
8801 SKOKIE 88 - 3
GOLF MILL
138
138
0.20
1113 ACSR
511
8802 SKOKIE 88 - 1
GOLF MILL
138
138
0.07
4.27
1
1113 ACSR
512
8802 SKOKIE 88 - 2
GOLF MILL
138
138
0.04
1113 ACSR
513
8802 SKOKIE 88 - 3
GOLF MILL
138
138
0.15
1113 ACSR
514
8803 SKOKIE 88 - 1
DEVON
138
138
0.09
1.78
1
900,1113 ACSR
515
8803 SKOKIE 88 - 2
DEVON
138
138
0.15
1.45
1113 ACSR
516
8803 SKOKIE 88 - 3
DEVON
138
138
0.17
900,1113 ACSR
517
8805 SKOKIE 88 - 1
NORTHBROOK 159
138
138
3.95
1
1113 ACSR
518
8805 SKOKIE 88 - 2
NORTHBROOK 159
138
138
0.85
0.73
1113 ACSR
519
8806 SKOKIE 88 - 1
NORTHBROOK 159
138
138
0.28
4.33
1
1113 ACSR
520
8806 SKOKIE 88 - 2
NORTHBROOK 159
138
138
0.71
0.23
1113 ACSR
521
8809 SKOKIE 88 - 1
DEVON
138
138
0.09
1.86
1
1113 ACSR
522
8809 SKOKIE 88 - 2
DEVON
138
138
0.27
1.42
1113 ACSR
523
8810 SKOKIE 88 - 1
DEVON
138
138
3.49
1
1113 ACSR
524
8810 SKOKIE 88 - 2
DEVON
138
138
0.19
1113 ACSR
525
8603 DAVIS CREEK - 1
BRADLEY
138
138
0.33
1
1113 ACSR
526
8603 DAVIS CREEK - 2
BRADLEY
138
138
6.00
2-556.5,1113 ACSR
527
8603 TAP - 1
CSL BEHRING
138
138
0.59
1113 ACSR
528
8605 DAVIS CREEK - 1
BRADLEY
138
138
2.15
2.51
1
2-556.5,1113 ACSR
529
8605 DAVIS CREEK - 2
BRADLEY
138
138
2.94
1113 ACSR
530
8605 TAP - 1
CSL BEHRING
138
138
0.12
0.51
2-556.5,1113 ACSR
531
9117 CARGO COURT - 1
SHOREWOOD
138
138
3.21
1
1113 AA
532
9117 CARGO COURT - 2
SHOREWOOD
138
138
0.49
4.24
1113 ACSR
533
10117 ITASCA - 1
TONNE
138
138
0.12
0.43
1
2156 ACSR
534
10117 ITASCA - 2
TONNE
138
138
1.32
1033.5 ACSS/TW
535
10118 ITASCA - 1
TONNE
138
138
0.13
0.44
1
2156 ACSR
536
10118 ITASCA - 2
TONNE
138
138
1.29
1033.5 ACSS/TW
537
10301 LISLE - 1
LOMBARD
138
138
0.53
7.93
1
1113,2156,2-1113A
538
10301 LISLE - 2
LOMBARD
138
138
0.32
900 ACSR
539
10301 LISLE - 3
LOMBARD
138
138
0.06
1113, 2156 ACSR
540
10302 LISLE - 1
LOMBARD
138
138
0.18
1
900 ACSR
541
10302 LISLE - 2
LOMBARD
138
138
0.57
8.06
1113,2156,2-1113A
542
10314 LISLE
BOLINGBROOK
138
138
0.16
7.41
1
1113, 2-556.6ACSR
543
10319 LISLE - 1
BOLINGBROOK
138
138
0.03
1
1113ACSR
544
10319 LISLE - 2
BOLINGBROOK
138
138
7.54
1113, 2-556.6ACSR
545
10714 DIXON - 1
MCGIRR ROAD
138
138
1.57
1
763.0ACSR/TW,
546
10714 DIXON - 2
MCGIRR ROAD
138
138
23.42
763.0ACSR/TW, 2-5
547
10721 DIXON - 1
STILLMAN VALLEY
136
138
10.49
3.94
1
1113 ACSR, 2156
548
10721 DIXON - 2
STILLMAN VALLEY
138
138
1.53
1113 ACSR, 2-556R
549
10721 DIXON - 3
STILLMAN VALLEY
138
138
0.16
1113 ACSR
550
10721 DIXON - 4
STILLMAN VALLEY
138
138
17.64
1113 ACSR, 2-1277
551
11102 ELECTRIC JUNCTION - 1
WOLFS
138
138
0.54
5.51
1
1113 ACSR, 1033.5
552
11102 ELECTRIC JUNCTION - 2
WOLFS
138
138
0.24
1113 ACSR
553
11103 ELECTRIC JUNCTION - 1
AURORA E.C.
138
138
0.11
1
1113 ACSR
554
11103 ELECTRIC JUNCTION - 2
AURORA E.C.
138
138
1.15
1113 ACSR
555
11105 ELECTRIC JUNCTION - 1
AURORA E.C.
138
138
0.32
0.74
1
1113 ACSR
556
11105 ELECTRIC JUNCTION - 2
AURORA E.C.
138
138
0.05
0.07
1113 ACSR
557
11106 ELECTRIC JUNCTION - 1
WATERMAN
138
138
0.30
9.35
1
1113 ACSR
558
11106 ELECTRIC JUNCTION - 2
WATERMAN
138
138
19.31
0.48
2-556.5 ACSR
559
11106 TAP
CREGO ROAD
138
138
3.97
2-556.5 ACSR,1113
560
11107 ELECTRIC JUNCTION - 1
NAPERVILLE
138
138
0.20
1.27
1
1113 ACSR
561
11107 ELECTRIC JUNCTION - 2
NAPERVILLE
138
138
1.40
1113 ACSR
562
11107 ELECTRIC JUNCTION - 3
NAPERVILLE
138
138
0.07
2-556.5,1113 ACSR
563
11110 ELECTRIC JUNCTION - 1
WOLFS
138
138
2.74
3.22
1
2-556.5,1113 ACSR
564
11110 ELECTRIC JUNCTION - 2
WOLFS
138
138
0.25
2156 ACSR
565
11110 TAP - 1
NAPERVILLE
138
138
0.06
1.27
1113 ACSR
566
11110 TAP - 2
NAPERVILLE
138
138
0.05
1113 ACSR
567
11301WATERMAN - 1
SANDWICH
138
138
0.89
0.48
1
1113 ACSR
568
11301WATERMAN - 2
SANDWICH
138
138
14.16
2-556.5,1113 ACSR
569
11301 TAP
ROW BREAKER AT
138
138
0.01
1113 ACSR
570
11323 WATERMAN
HAUMESSER ROAD
138
138
5.46
1
664.8 ACSS/TW, 11
571
11323 TAP
CREGO ROAD
138
138
5.41
2-556.4, 2156ACSR
572
11413 NORTHWEST
CLYBOURN-CROSBY
138
138
0.02
0.09
1
1113 ACSR
573
11416 NORTHWEST - 1
SKOKIE 88
138
138
1.68
1.89
1
750 CU / 1113 ACS
574
11416 NORTHWEST - 2
SKOKIE 88
138
138
0.06
1113 ACSR
575
11418 NORTHWEST
CROSBY
138
138
0.05
0.09
1
266.8 ACSR
576
11603 GOODINGS GROVE - 1
CRESTWOOD
138
138
11.32
1
1113 ACSR
577
11603 GOODINGS GROVE - 2
CRESTWOOD
138
138
0.05
1113 ACSR
578
11603 GOODINGS GROVE - 3
CRESTWOOD
138
138
0.16
1113 ACSR
579
11605 GOODINGS GROVE
BEDFORD PARK
138
138
18.45
1
900,1113 ACSR
580
11606 GOODINGS GROVE
BEDFORD PARK
138
138
0.71
17.77
1
900 ACSR
581
11609 GOODINGS GROVE - 1
CRESTWOOD
138
138
0.66
10.53
1
1113 ACSR
582
11609 GOODINGS GROVE - 2
CRESTWOOD
138
138
0.24
1113 ACSR
583
11609 GOODINGS GROVE - 3
CRESTWOOD
138
138
0.04
1113 ACSR
584
11701 PROSPECT HTS - 1
DES PLAINES 46
138
138
0.30
3.90
1
1113 ACSR
585
11701 PROSPECT HTS - 2
DES PLAINES 46
138
138
0.23
0.35
1113 ACSR
586
11701 PROSPECT HTS - 3
DES PLAINES 46
138
138
0.11
1113 ACSR
587
11702 PROSPECT HTS - 1
DES PLAINES 46
138
138
0.25
0.35
1
1113 ACSR
588
11702 PROSPECT HTS - 2
DES PLAINES 46
138
138
0.63
3.66
1113 ACSR
589
11702 PROSPECT HTS - 3
DES PLAINES 46
138
138
0.09
1113 ACSR
590
11704 PROSPECT HEIGHTS - 1
APTAKISIC
138
138
0.13
5.41
1
1113 ACSR
591
11704 PROSPECT HEIGHTS - 2
APTAKISIC
138
138
0.22
1113 ACSR
592
11708 PROSPECT HEIGHTS - 1
APTAKISIC
138
138
0.30
5.46
1
1113 ACSR
593
11708 PROSPECT HEIGHTS - 2
APTAKISIC
138
138
0.10
0.03
266.8, 636, 1113A
594
11902 LANCASTER - 1
MARYLAND
138
138
15.89
4.13
1
1113 ACSR
595
11902 LANCASTER - 2
MARYLAND
138
138
1.25
0.69
1113 ACSR
596
11902 LANCASTER - 3
MARYLAND
138
138
0.10
1.01
1113 ACSR,
597
11904 LANCASTER - 1
ECOGROVE WIND FARM
138
138
0.47
1
636, 1113 ACSR
598
11904 LANCASTER - 2
ECOGROVE WIND FARM
138
138
9.46
636, 1113 ACSR
599
11904 LANCASTER - 3
ECOGROVE WIND FARM
138
138
2.24
636 ACSR
600
11904 TAP
FREEPORT
138
138
1.13
266.8, 636, 1113A
601
12007 LOMBARD - 1
ELMHURST
138
138
8.14
1
1113 ACSR
602
12007 LOMBARD - 2
ELMHURST
138
138
0.06
1113 ACSR
603
12008 LOMBARD - 1
ELMHURST
138
138
0.10
8.16
1
900,1113 ACSR
604
12008 LOMBARD - 2
ELMHURST
138
138
0.11
1113 ACSR
605
12015 LOMBARD - 1
ITASCA
138
138
8.12
1
1113 ACSR
606
12015 LOMBARD - 2
ITASCA
138
138
0.09
1113 ACSR
607
12016 LOMBARD - 1
ITASCA
138
138
0.58
7.45
1
1113 ACSR
608
12016 LOMBARD - 2
ITASCA
138
138
0.10
1113 ACSR
609
12016 LOMBARD - 3
ITASCA
138
138
0.29
1113 ACSR
610
12204 BELVEDERE - 1
PLEASANT VALLEY
138
138
22.72
1
1113 ACSR, 664.8A
611
12204 BELVEDERE - 2
PLEASANT VALLEY
138
138
0.63
664.8ACSS/TW
612
12204 TAP
MARENGO
138
138
1.17
477, 1113 ACSR, 6
613
12205 BELVIDERE - 1
WOODSTOCK
138
138
0.21
21.26
1
1113
614
12205 BELVIDERE - 2
WOODSTOCK
138
138
2.71
2-556.5 ACSR,1113
615
12205 TAP
MARENGO
138
138
1.22
477 ACSR
616
12411 MARYLAND - 1
DIXON
138
138
1.45
1
3/0 CO
617
12411 MARYLAND - 2
DIXON
138
138
11.32
1113 ACSR
618
12411 MARYLAND - 3
DIXON
138
138
2.73
3/0 CO
619
12411 TAP
STERLING
138
138
14.38
1113 ACS
620
13219 GARDEN PLAIN
I.S.P.C.O.
138
138
4.52
1
477 ACSR
621
13304 ROCK FALLS
SCHAUFF ROAD
138
138
11.09
2-556.5, 2156ACSR
622
13501 ELMHURST - 1
BELLWOOD
138
138
0.19
5.31
1
900,1113 ACSR
623
13501 ELMHURST - 2
BELLWOOD
138
138
0.07
900,1113 ACSR
624
13501 ELMHURST - 3
BELLWOOD
138
138
0.07
900,1113 ACSR
625
13502 ELMHURST - 1
BELLWOOD
138
138
0.15
5.29
1
900,1113 ACSR
626
13502 ELMHURST - 2
BELLWOOD
138
138
0.11
900,1113 ACSR
627
13502 ELMHURST - 3
BELLWOOD
138
138
0.05
900,1113 ACSR
628
13503 ELMHURST - 1
NORTHLAKE
138
138
0.30
0.42
1
900,1113 ACSR
629
13503 ELMHURST - 2
NORTHLAKE
138
138
0.16
900 ACSR
630
13504 ELMHURST - 1
FRANKLIN PARK
138
138
0.13
0.40
1
1113 ACSR
631
13504 ELMHURST - 2
FRANKLIN PARK
138
138
1.77
0.14
1113 ACSR
632
13504 ELMHURST - 3
FRANKLIN PARK
138
138
0.12
1113 ACSR
633
13510 ELMHURST - 1
FRANKLIN PARK
138
138
0.10
0.46
1
900,1113 ACSR
634
13510 ELMHURST - 2
FRANKLIN PARK
138
138
0.03
1.77
1113 ACSR
635
13510 ELMHURST - 3
FRANKLIN PARK
138
138
0.22
1113 ACSR
636
13803 STATE LINE
NIPSCO
138
138
0.19
1
900,1113 ACSR
637
13805 SILVER LAKE - 1
SW TIE L-18513
138
138
0.23
4.00
1
1113,2156 ACSR
638
13805 SILVER LAKE - 2
SW TIE L-18513
138
138
0.32
7.06
1277.2 ACSR
639
13805 SILVER LAKE - 3
SW TIE L-18513
138
138
0.11
1113 ACSR
640
13805 SILVER LAKE - 4
SW TIE L-18513
138
138
0.22
1113 ACSR
641
13806 SILVER LAKE - 1
SW TIE L-18512
138
138
0.21
3.91
1
1277.2 ACAR, 477,
642
13806 SILVER LAKE - 2
SW TIE L-18512
138
138
0.36
7.05
1277.2 ACAR
643
13806 SILVER LAKE - 3
SW TIE L-18513
138
138
0.18
477,1113 ACSR
644
13806 SILVER LAKE - 4
SW TIE L-18513
138
138
0.22
477,1113 ACSR
645
13808 SILVER LAKE - 1
CRYSTAL LAKE
138
138
0.09
2.58
1
1113 ACSR
646
13808 SILVER LAKE - 2
CRYSTAL LAKE
138
138
0.07
1113 ACSR
647
13809 SILVER LAKE - 1
PLEASANT VALLEY
138
138
2.39
7.33
1
477,1113 ACSR
648
13809 SILVER LAKE - 2
PLEASANT VALLEY
138
138
0.14
1113 ACSR
649
14101 PLEASANT VALLEY - 1
CRYSTAL LAKE
138
138
0.01
6.77
1
477,1113 ACSR
650
14101 PLEASANT VALLEY - 2
CRYSTAL LAKE
138
138
0.05
0.12
477,1113 ACSR
651
14101 PLEASANT VALLEY - 3
CRYSTAL LAKE
138
138
0.09
477,1113 ACSR
652
14101 PLEASANT VALLEY - 4
CRYSTAL LAKE
138
138
0.08
477,1113 ACSR
653
14102 PLEASANT VALLEY
TOLLWAY
138
138
26.47
0.96
1
1113 ACSR, 2-556R
654
14103 PLEASANT VALLEY
TOLLWAY
138
138
0.26
27.20
1
1113 ACSR, 2-556R
655
14106 PLEASANT VALLEY - 1
WOODSTOCK
138
138
3.06
1
664.8 ACSS/TW
656
14106 PLEASANT VALLEY - 2
WOODSTOCK
138
138
0.16
0.51
1113 ACSR, 664.8
657
14302 WOLFS - 1
PLANO
138
138
0.14
1
1113 ACSR
658
14302 WOLFS - 2
PLANO
138
138
6.35
477,1113
659
14302 WOLFS - 3
PLANO
138
138
7.00
1113,2156 ACSR
660
14302 TAP
ROW BREAKER AT
138
138
0.02
1113 ACSR
661
14304 WOLFS - 1
PLANO
138
138
0.14
1
1113ACSR
662
14304 WOLFS - 2
PLANO
138
138
6.35
477,1113
663
14304 WOLFS - 3
PLANO
138
138
0.21
6.79
1113, 2156 ACSR
664
14403 WAYNE - 1
AURORA E.C.
138
138
0.01
12.04
1
1113 ACSR
665
14403 WAYNE - 2
AURORA E.C.
138
138
0.30
0.16
1113 ACSR
666
14405 WAYNE - 1
AURORA E.C.
138
138
0.21
11.76
1
1113 ACSR
667
14405 WAYNE - 2
AURORA E.C.
138
138
0.41
0.17
1113 ACSR
668
14609 SANDWICH - 1
PLANO
138
138
0.12
1
1113 ACSR
669
14609 SANDWICH - 2
PLANO
138
138
9.58
1113 ACSR
670
15001 CALUMET
RIVER E.C.
138
138
0.30
1.86
1
636,1113 ACSR
671
15002 CALUMET
RIVER E.C.
138
138
0.34
1.87
1
477,1113 ACSR
672
15410 LIBERTYVILLE - 1
APTAKISIC
138
138
0.25
9.17
1
1113 ACSR
673
15410 LIBERTYVILLE - 2
APTAKISIC
138
138
0.41
1113 ACSR
674
15417 LIBERTYVILLE - 1
APTAKISIC
138
138
0.54
9.10
1
1113 ACSR
675
15417 LIBERTYVILLE - 2
APTAKISIC
138
138
0.17
0.04
1113 ACSR
676
15507 NELSON - 1
DIXON 107
138
138
0.48
9.11
1
477,1113 ACSR
677
15507 NELSON - 2
DIXON 107
138
138
0.78
477,1113 ACSR
678
15508 NELSON - 1
DIXON 107
138
138
9.12
0.47
1
477,1113 ACSR
679
15508 NELSON - 2
DIXON 107
138
138
0.78
477,1113 ACSR
680
15509 NELSON
ROCK FALLS
138
138
2.87
1
1113 ACSR
681
15511 NELSON - 1
DIXON R/W
138
138
0.71
1
1113 ACSR
682
15511 NELSON - 2
DIXON R/W
138
138
4.97
1113 ACSR
683
15511 TAP
STERLING
138
138
0.05
312.8 AAAC / 1113
684
15518 NELSON - 1
GARDEN PLAIN
138
138
0.22
2.62
1
266.8,477,1113 AC
685
15518 NELSON - 2
GARDEN PLAIN
138
138
16.72
1113 AA / 477 ACS
686
15518 NELSON - 3
GARDEN PLAIN
138
138
7.88
266.8 ACSR
687
15518 NELSON - 4
GARDEN PLAIN
138
138
1.49
477 ACSR
688
15518 TAP
ROCK FALLS
138
138
0.04
1113 ACSR
689
15621 CHERRY VALLEY - 1
DIXON
138
138
1.15
1
1113 ACSR
690
15621 CHERRY VALLEY - 2
DIXON
138
138
0.03
1113 ACSR
691
15621 CHERRY VALLEY - 3
DIXON
138
138
16.81
1113 ACSR
692
15622 CHERRY VALLEY - 1
SABROOKE
138
138
0.07
0.36
1
1113 ACSR
693
15622 CHERRY VALLEY - 2
SABROOKE
138
138
7.16
1113 ACSR
694
15623 CHERRY VALLEY - 1
BELVIDERE
138
138
3.85
4.74
1
1277.2 ACAR / 215
695
15623 CHERRY VALLEY - 2
BELVIDERE
138
138
0.16
1277.2 ACAR / 215
696
15624 CHERRY VALLEY - 1
BELVIDERE
138
138
0.34
1.17
1
1113 ACSR
697
15624 CHERRY VALLEY - 2
BELVIDERE
138
138
6.53
1113 ACSR
698
15624 CHERRY VALLEY - 3
BELVIDERE
138
138
0.10
1113 ACSR
699
15625 CHERRY VALLEY - 1
WEMPLETOWN
138
138
0.44
22.39
1
1113,2156 ACSR
700
15625 CHERRY VALLEY - 2
WEMPLETOWN
138
138
0.10
2.60
1113,2-556.5 ASCR
701
15625 CHERRY VALLEY - 3
WEMPLETOWN
138
138
0.06
1113 ACSR
702
15626 CHERRY VALLEY - 1
SABROOKE
138
138
0.10
0.36
1
1113 ACSR
703
15626 CHERRY VALLEY - 2
SABROOKE
138
138
7.15
1113 ACSR
704
15627 CHERRY VALLEY - 1
GLIDDEN
138
138
21.00
0.98
1
1113,2156 ACSR
705
15627 CHERRY VALLEY - 2
GLIDDEN
138
138
7.15
1113 ACSR
706
15912 NORTHBROOK 159 - 1
HIGHLAND PARK
138
138
4.02
1
1113 ACSR
707
15912 NORTHBROOK 159 - 2
HIGHLAND PARK
138
138
0.35
0.35
1113 ACSR,2156 ACSR
708
15913 NORTHBROOK 159 - 1
HIGHLAND PARK
138
138
4.12
1
1113 ACSR
709
15913 NORTHBROOK 159 - 2
HIGHLAND PARK
138
138
0.73
1113,2156 ACSR
710
16901 MCGIRR ROAD - 1
SHADY OAKS
138
138
11.29
1
1113 ACSR
711
16901 MCGIRR ROAD - 2
SHADY OAKS
138
138
0.09
1113 ACSR
712
16901 TAP
MENDOTA HILLS
138
138
0.04
1113 ACSR
713
16914 MCGIRR ROAD - 1
STEWARD
138
138
0.22
0.01
1
1113 ACSR
714
16914 MCGIRR ROAD - 2
STEWARD
138
138
1.21
1113 ACSR
715
16914 TAP - 1
RITCHIE ROAD
138
138
1.08
266.8 ACSR
716
16914 TAP - 2
RITCHIE ROAD
138
138
4.19
556.5, 1113 ACSR, T2-556.5 ACSR
717
17008 HARBOR
UNIVERSITY
138
138
0.50
5.45
1
1113,2156 ACSR
718
17113 SABROOKE - 1
WEMPLETOWN
138
138
3.69
0.34
1
1113 ACSR
719
17113 SABROOKE - 2
WEMPLETOWN
138
138
2.95
3.71
1113 ACSR
720
17113 SABROOKE - 3
WEMPLETOWN
138
138
0.33
1113 ACSR
721
17113 SABROOKE - 4
WEMPLETOWN
138
138
0.20
1
1113 ACSR
722
17121 WEMPLETOWN - 1
LANCASTER
138
138
1.03
1
1113 ACSR
723
17121 WEMPLETOWN - 2
LANCASTER
138
138
22.17
477,1113 ACSR
724
17712 BURNHAM - 1
CHICAGO HTS
138
138
0.56
1
1113 ACSR
725
17712 BURNHAM - 2
CHICAGO HTS
138
138
9.42
1113 ACSR
726
17713 BURNHAM - 1
WILDWOOD
138
138
5.05
1
900,1113 ACSR
727
17713 BURNHAM - 2
WILDWOOD
138
138
0.40
1113 ACSR
728
17714 BURNHAM - 1
WILDWOOD
138
138
5.13
1
900,1113 ACSR
729
17714 BURNHAM - 2
WILDWOOD
138
138
0.13
0.13
1113 ACSR
730
17714 TAP
HEGEWISCH
138
138
0.33
1.89
1113 ACSR
731
17715 BURNHAM - 1
TOWER AUTOMOTIVE
138
138
2.27
1
1113 ACSR
732
17715 BURNHAM - 2
TOWER AUTOMOTIVE
138
138
0.36
0.08
1113 ACSR
733
17903 BLOOM
MATTESON
138
138
6.07
1
1113 ACSR
734
17904 BLOOM
MATTESON
138
138
0.25
5.82
1
1113 ACSR
735
18512 TOLLWAY
SW TIE L-13806
138
138
2.80
1
1277.2 ACAR /111
736
18512 TAP
ROCKY ROAD E.C.
138
138
0.01
1277.2 ACAR
737
18513 TOLLWAY
SW TIE L-13805
138
138
0.58
2.24
1
1277.2 ACAR / 111
738
18513 TAP
ROCKY ROAD E.C.
138
138
0.03
1113 ACSR
739
18706 SCHAUFF ROAD - 1
KEEMIN (AMEREN)
138
138
0.07
1
740
18706 SCHAUFF ROAD - 2
KEEMIN (AMEREN)
138
138
24.88
477 ACSR
741
18618 STEWARD - 1
TWOMBLY ROAD
138
138
11.26
1
556.5 ACSR
742
18618 STEWARD - 2
TWOMBLY ROAD
138
138
0.10
556.5 ACSR
743
18623 STEWARD
HAUMESSER ROAD
138
138
7.21
1
1113 ACSR, 664.8A
744
19414 SABROOKE - 1
LANCASTER
138
138
2.35
1
636,1113 ACSR
745
19414 SABROOKE - 2
LANCASTER
138
138
6.95
1113 ACSR
746
19414 SABROOKE - 3
LANCASTER
138
138
21.14
1113 ACSR
747
28201 ZION TDC 282 - 1
IL-WI STATE LINE
138
138
0.10
1.79
1
1113 ACSR
748
28201 ZION TDC 282 - 2
IL-WI STATE LINE
138
138
0.25
0.14
1113 ACSR
749
28201 ZION TDC 282 - 3
IL-WI STATE LINE
138
138
1.79
477 ACSR
750
52517 NORMANTOWN
BOLINGBROOK
138
138
0.16
2.81
1
751
138KV LINES
138kV LINES
752
0702 ILL-IND STATE LINE
WASHINGTON PARK
138
138
8.44
1
800 MM2 XLPE
753
0705 ILL-IND STATE LINE
WASHINGTON PARK
138
138
9.75
800 MM2 XLPE
754
1106 QUARY
STATE
138
138
2.27
1200 MM2 XLPE / 2
755
1106 FISK
TERMINAL
138
138
0.15
1600 kcmil XLPE
756
1108 QUARY
STATE
138
138
2.26
1200 MM2 XLPE
757
1110 FISK
DEKOVEN
138
138
2.16
1
1600 MM2 XLPE
758
1111 FISK
DEKOVEN
138
138
2.28
1
1600 MM2 XLPE
759
1306 RIDGELAND
LEXTENSION PT
138
138
0.31
1600 MM2 XLPE
760
1317 CRAWFORD
FISK
138
138
4.46
1
2500 HPFF
761
1318 CRAWFORD
FISK
138
138
4.49
1
2500 HPFF
762
1320 CRAWFORD
JEFFERSON
138
138
6.93
1
800 MM2 XLPE
763
1322 CRAWFORD
HAYFORD
138
138
0.34
1600 MM2 XLPE
764
1324 CRAWFORD
HAYFORD
138
138
0.33
1600 MM2 XLPE
765
1326 CRAWFORD
JEFFERSON
138
138
6.72
1
800 MM2 XLPE
766
3610 DEKOVEN
MADISON
138
138
1.07
1
1600 MM2 XLPE
767
3611 DEKOVEN
MADISON
138
138
1.07
1
1600 MM2 XLPE
768
3701Y NATOMA
GALEWOOD
138
138
0.37
1
250 kcmil HPFF
769
3702Y NATOMA
GALEWOOD
138
138
0.43
1
350 kcmil HPFF
770
3703Y NATOMA
GALEWOOD
138
138
0.37
1
250 kcmil HPFF
771
3704Y NATOMA
GALEWOOD
138
138
0.37
1
250 kcmil HPFF
772
3710 FRANKLIN PARK
NATOMA
138
138
5.46
1
2000 kcmil HPFF
773
3705 NATOMA
FRANKLIN PARK
138
138
6.09
1
2000 kcmil HPFF
774
3706 NATOMA
HIGGINS
138
138
4.56
1
2000 kcmil HPFF
775
3707 NATOMA
NORRIDGE
138
138
4.56
1
2000 kcmil HPFF
776
3709 NATOMA
OAK PARK
138
138
3.14
1
2000 kcmil HPFF
777
4522 FISK
JEFFERSON
138
138
2.14
1
2500 kcmil HPFF
778
4523 FISK
JEFFERSON
138
138
2.13
1
2500 kcmil HPFF
779
4525 JEFFERSON
GRAND
138
138
1.94
1
1600 MM2 XLPE
780
4527 JEFFERSON
GRAND
138
138
1.87
1
1600 MM2 XLPE
781
4018 DIVERSEY
CROSBY
138
138
2.59
1
2500 kcmil HPFF
782
4607 DESPLAINES
HIGGINS
138
138
7.57
1
2000 kcmil HPFF
783
5105X RIDGELAND
TERMINAL C
138
138
0.24
1600 MM2 XLPE
784
5105Y RIDGELAND
TERMINAL C
138
138
0.17
1600 MM2 XLPE
785
5107X MCCOOK
TERMINAL O
138
138
0.08
1600 MM2 XLPE
786
5107Y MCCOOK
TERMINAL Q
138
138
0.08
1600 MM2 XLPE
787
5810 MADISON
GRAND
138
138
1.17
1
1600 MM2 XLPE
788
5811 MADISON
GRAND
138
138
1.17
1
1600 MM2 XLPE
789
5825 GRAND
CROSBY
138
138
1.05
1
1600 MM2 XLPE
790
5826 GRAND
WEST LOOP
138
138
1.50
1
1600 MM2 XLPE
791
5827 GRAND
CROSBY
138
138
0.94
1
1600 MM2 XLPE
792
5828 GRAND
WEST LOOP
138
138
1.40
1
1600 MM2 XLPE
793
8221 CROSBY
ROCKWELL
138
138
1.95
1600 MM2 XLPE
794
8223 CROSBY
ROCKWELL
138
138
1.95
1600 MM2 XLPE
795
11411 NORTHWEST
DEVON
138
138
5.62
1
2000 kcmil HPFF
796
11412 NORTHWEST
NATOMA
138
138
6.45
1
2000 kcmil HPFF
797
11413 NORTHWEST
DIVERSEY
138
138
1.86
2000 kcmil HPFF,2
798
11416 NORTHWEST
DEVON
138
138
5.85
800 MM2 XLPE
799
11417 NORTHWEST
NATOMA
138
138
6.08
1
2000 kcmil HPFF
800
11418 ADDISON RIVER
DIVERSEY
138
138
1.70
2000 kcmil HPFF
801
13503 NORTHLAKE
FRANKLIN PARK
138
138
1.54
2000 kcmil HPFF
802
13701 WASHINGTON PARK
JEFFERSON
138
138
8.25
1
800 MM2 XLPE
803
13701 JEFFERSON
GRENSHAW
138
138
0.52
2500 kcmil HPFF
804
14807 WEST LOOP
CLYBOURN
138
138
1.55
1
1600 mm2 XLPE
805
14818 WEST LOOP
DIVERSEY
138
138
3.24
1
1600 MM2 XLPE
806
14826 WEST LOOP
CROSBY
138
138
0.55
1
1600 MM2 XLPE
807
14828 WEST LOOP
CROSBY
138
138
0.65
1
1600 MM2 XLPE
808
15301 TAYLOR
GRENSHAW
138
138
0.20
1
1600 MM2 XLPE
809
15302 TAYLOR
JEFFERSON
138
138
0.91
1
2000 kcmil HPFF
810
15303 TAYLOR
JEFFERSON
138
138
0.50
1
2500 kcmil HPFF
811
15310 TAYLOR
GRENSHAW
138
138
0.19
1
1600 MM2 XLPE
812
15315 LASALLE
STATE
138
138
0.91
1
1200 MM2 XPLE
813
15315 TAYLOR
LASALLE
138
138
0.82
2500 kcmil HPFF
814
15316 TAYLOR
LASALLE
138
138
0.77
1
2500 kcmil HPFF
815
15317 TAYLOR
LASALLE
138
138
0.76
1
2500 kcmil HPFF
816
15317 LASALLE
STATE
138
138
0.91
1200 MM2 XPLE
817
15318 TAYLOR
LASALLE
138
138
0.78
1
2500 kcmil HPFF
818
17008 61ST STREET
UNIVERSITY
138
138
2.45
2000 kcmil HPFF
819
17401 UNIVERSITY
GRENSHAW
138
138
6.49
1
2000 kcmil HPFF
820
17404 UNIVERSITY
WASHINGTON PARK
138
138
2.20
1
2000 kcmil HPFF
821
19209 RIDGELAND
OAK PARK
138
138
5.35
1
2000 kcmil HPFF
822
19801 DESPLAINES
NORRIDGE
138
138
4.67
1
2000 kcmil HPFF
823
7405 KEWANEE - 1
SCHAUFF  ROAD
138
138
0.06
1
1590ACSR
824
7405 KEWANEE - 2
SCHAUFF  ROAD
138
138
31.70
477ACSR
825
18702 SCHAUFF ROAD
ROCK FALLS
138
138
0.12
11.01
1
2-556.5, 1590ACSR
826
8302 GLIDDEN
CREGO ROAD
138
138
3.63
1
2-556.5 ACSR, 2156 ACSR
827
8309 GLIDDEN
CREGO ROAD
138
138
5.09
1
2-556.5, 2156 ACSR
828
15515 NELSON
SCHAUFF ROAD
138
138
17.55
1
2-556.5, 1590 ACSR
829
18407 ELK GROVE - 1
TONNE
138
138
0.16
1
1113 ACSR
830
18407 ELK GROVE - 2
TONNE
138
138
0.09
2.39
1113 ACSR
831
18408 ELK GROVE - 1
TONNE
138
138
0.24
1
1113 ACSR
832
18408 ELK GROVE - 2
TONNE
138
138
2.39
1113 ACSR
833
1 RITCHIE ROAD
CARON ROAD
138
138
1.45
1
556.5, T2-556.5 ACSR
834
59306 WILLOW SPRINGS - 1
BURR RIDGE
138
138
0.07
5.14
1
1113 ACSR
835
59306 WILLOW SPRINGS - 2
BURR RIDGE
138
138
0.12
0.11
1113 ACSR
836
59306 WILLOW SPRINGS - 3
BURR RIDGE
138
138
0.05
1113 ACSR
837
8604 DAVIS CREEK - 1
BRADLEY
138
138
5.48
0.94
1
1113, T2-556.5, ACSR
838
8604 DAVIS CREEK - 2
BRADLEY
138
138
0.00
0.28
1113 ACSR
839
8604 DAVIS CREEK - 3
BRADLEY
138
138
0.08
1113 ACSR
840
7404 KEWANEE - 1
PUTNAM (AMEREN)
138
138
31.90
1
477 ACSR
841
7404 KEWANEE - 2
PUTNAM (AMEREN)
138
138
0.14
0.29
2-556.5 ACSR
842
98105 CRESCENT RIDGE - 1
CORBIN (AMEREN)
138
138
0.28
0.48
1
477,1113,2-556.5 ACSR
843
98105 CRESCENT RIDGE - 2
CORBIN (AMEREN)
138
138
27.48
477 ACSR
844
19906 KENSINGTON
CSL BEHRING
138
138
4.77
1
1113 ACSR
845
19907 KENSINGTON
CSL BEHRING
138
138
0.13
4.64
1
1113 ACSR
36 TOTAL
3,055
1,954
391
131,588,062
2,813,264,683
2,944,852,745


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: TransmissionLineStartPoint
The statistical data on pages 422 through 423 excludes High Voltage Distribution lines consistent with the Plant in Service balance reported on pages 422 and 423, columns (j), (k) and (l), rows 1, 2, and 3.
(b) Concept: TransmissionLineStartPoint
10808 from Lockport to Lombard was merged with 12001 from Lombard to Itasca in 2024. The result is one line, 10808 from Lockport to Itasca, that contains all the mileage of the two former lines. 12001 has been removed.

Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
TRANSMISSION LINES ADDED DURING YEAR
  1. Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines.
  2. Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (l) to (o), it is permissible to report in these columns the costs. Designate, however, if estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (l) with appropriate footnote, and costs of Underground Conduit in column (m).
  3. If design voltage differs from operating voltage, indicate such fact by footnote; also where line is other than 60 cycle, 3 phase, indicate such other characteristic.
LINE DESIGNATION SUPPORTING STRUCTURE CIRCUITS PER STRUCTURE CONDUCTORS LINE COST
Line No.
TransmissionLineStartPoint
From
TransmissionLineEndPoint
To
LengthOfTransmissionLineAdded
Line Length in Miles
SupportingStructureOfTransmissionLineType
Type
AverageNumberOfSupportingStructuresOfTransmissionLinePerMiles
Average Number per Miles
NumberOfTransmissionCircuitsPerStructurePresent
Present
NumberOfTransmissionCircuitsPerStructureUltimate
Ultimate
ConductorSize
Size
ConductorSpecification
Specification
ConductorConfigurationAndSpacing
Configuration and Spacing
OperatingVoltageOfTransmissionLine
Voltage KV (Operating)
CostOfLandAndLandRightsTransmissionLinesAdded
Land and Land Rights
CostOfPolesTowersAndFixturesTransmissionLinesAdded
Poles, Towers and Fixtures
CostOfConductorsAndDevicesTransmissionLinesAdded
Conductors and Devices
Asset Retire. Costs
CostOfTransmissionLinesAdded
Total
SupportingStructureConstructionType
Construction
(a)
(b)
(c)
(d)
(e)
(f)
(g)
(h)
(i)
(j)
(k)
(l)
(m)
(n)
(o)
(p)
(q)
1
138 kV Overhead
2
Line Sections Installed
3
Total - 1
4
345 kV Overhead
5
Total - 2
44
TOTAL
0.00
0
0
0


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
SUBSTATIONS
  1. Report below the information called for concerning substations of the respondent as of the end of the year.
  2. Substations which serve only one industrial or street railway customer should not be listed below.
  3. Substations with capacities of Less than 10 MVA except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown.
  4. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (f).
  5. Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity.
  6. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company.
Character of Substation VOLTAGE (In MVa) Conversion Apparatus and Special Equipment
Line No.
SubstationNameAndLocation
Name and Location of Substation
(a)
SubstationCharacterDescription
Transmission or Distribution
(b)
SubstationCharacterAttendedOrUnattended
Attended or Unattended
(b-1)
PrimaryVoltageLevel
Primary Voltage (In MVa)
(c)
SecondaryVoltageLevel
Secondary Voltage (In MVa)
(d)
TertiaryVoltageLevel
Tertiary Voltage (In MVa)
(e)
SubstationInServiceCapacity
Capacity of Substation (In Service) (In MVa)
(f)
NumberOfTransformersInService
Number of Transformers In Service
(g)
Number of Spare Transformers
(h)
ConversionApparatusAndSpecialEquipmentType
Type of Equipment
(i)
NumberOfConversionApparatusAndSpecialEquipmentUnits
Number of Units
(j)
CapacityOfConversionApparatusAndSpecialEquipment
Total Capacity (In MVa)
(k)
1
CHICAGO (OVER 10 MVA)
2
89-BEVERLY
Distribution
Unattended
138.00
12.50
132
4
3
150-CALUMET-1
Distribution
Attended
138.00
12.50
300
4
4
150-CALUMET-2
Distribution
Attended
138.00
69.00
120
3
5
54-CLYBOURN
Distribution
Unattended
138.00
12.50
200
4
6
30-COLUMBUS PARK-1
Distribution
Unattended
69.00
12.50
219
6
7
13-CRAWFORD-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
8
13-CRAWFORD-2
Distribution
Unattended
138.00
12.50
400
8
9
82-CROSBY
Distribution
Unattended
138.00
12.50
200
4
10
814-DAMEN
Distribution
Unattended
138.00
12.50
80
2
11
87-DEARBORN
Distribution
Unattended
69.00
12.50
160
4
12
110-DEVON
Distribution
Unattended
138.00
12.50
160
4
13
40-DIVERSEY
Distribution
Unattended
138.00
12.50
200
4
14
11-FISK-1
Transmission
Unattended
345.00
138.00
34.00
600
2
15
11-FISK-2
Distribution
Unattended
138.00
12.50
200
3
16
104-FORD CITY
Distribution
Unattended
138.00
12.50
100
3
17
31-GALEWOOD-1
Distribution
Unattended
138.00
12.50
160
4
18
90-DEKOVEN
Distribution
Unattended
138.00
69.00
400
2
19
32-HANSON PARK-1
Distribution
Unattended
138.00
12.50
160
4
20
33-HAYFORD
Distribution
Unattended
138.00
12.50
120
4
21
55-HEGEWISCH
Distribution
Unattended
138.00
12.50
146
4
22
71-HIGGINS
Distribution
Unattended
138.00
12.50
160
4
23
38-HUMBOLDT PARK-1
Distribution
Unattended
138.00
12.50
200
4
24
745-I.C.AIR RIGHTS
Distribution
Unattended
138.00
12.50
200
4
25
45-JEFFERSON-1
Distribution
Unattended
138.00
12.50
250
5
26
45-JEFFERSON-2
Distribution
Unattended
138.00
69.00
12.50
800
12
27
34-KINGSBURY
Distribution
Unattended
138.00
12.50
200
4
28
68-LA SALLE
Distribution
Unattended
138.00
12.50
200
4
29
36-MADISON
Distribution
Unattended
138.00
12.50
250
5
30
714-MEDICAL CENTER
Distribution
Unattended
138.00
12.50
200
4
31
37-NATOMA
Distribution
Unattended
138.00
12.50
100
2
32
648-NORRIDGE
Distribution
Unattended
138.00
12.50
160
4
33
114-NORTHWEST-1
Distribution
Unattended
138.00
12.50
12.50
375
5
34
114-NORTHWEST-2
Distribution
Unattended
138.00
12.50
160
4
35
65-OHIO
Distribution
Unattended
138.00
12.50
250
5
36
785-ONTARIO
Distribution
Unattended
138.00
12.50
200
4
37
49-PLYMOUTH COURT
Distribution
Unattended
69.00
12.50
160
4
38
39-PORTAGE
Distribution
Unattended
138.00
12.50
268
8
39
840-QUARRY
Distribution
Unattended
138.00
12.50
200
4
40
84-ROSEHILL
Distribution
Unattended
138.00
12.50
200
4
41
41-ROSELAND
Distribution
Unattended
69.00
12.50
99
3
42
63-SAWYER
Distribution
Unattended
138.00
12.50
132
4
43
784-SEARS
Distribution
Unattended
138.00
12.50
200
4
44
126-STATE
Distribution
Unattended
138.00
12.50
200
4
45
153-TAYLOR
Transmission
Unattended
345.00
138.00
34.00
600
2
46
174-UNIVERSITY
Distribution
Unattended
138.00
12.50
200
4
47
118-WALLACE
Distribution
Unattended
138.00
12.50
106
3
48
137-WASHINGTON PARK
Distribution
Unattended
138.00
12.50
225
3
49
148-WEST LOOP
Transmission
Unattended
345.00
138.00
34.00
600
2
50
43-WILDWOOD-1
Distribution
Unattended
138.00
12.50
66
2
51
X310-ALBANY PARK
Distribution
Unattended
12.50
4.00
22
3
52
Z300-ARCHER
Distribution
Unattended
12.50
4.00
11
3
53
Y310-AUSTIN
Distribution
Unattended
12.50
4.00
18
3
54
X301-BELMONT
Distribution
Unattended
12.50
4.00
22
3
55
679-BESLEY COURT
Distribution
Unattended
12.50
4.00
25
4
56
Y365-CAMPBELL
Distribution
Unattended
12.50
4.00
24
3
57
798-CARROLL
Distribution
Unattended
12.50
4.00
17
3
58
666-CENTER
Distribution
Unattended
12.50
4.00
15
2
59
X304-CHASE
Distribution
Unattended
34.00
4.00
15
2
60
X381-CORTLAND
Distribution
Unattended
12.50
4.00
22
3
61
750-CRAGIN
Distribution
Unattended
12.50
4.00
26
3
62
Z310-DREXEL
Distribution
Unattended
12.50
4.00
15
3
63
X300-EASTWOOD
Distribution
Unattended
12.50
4.00
24
3
64
Z312-EXCHANGE
Distribution
Unattended
12.50
4.00
15
3
65
31-GALEWOOD-2
Distribution
Unattended
12.50
4.00
15
3
66
834-GRAND CROSSING
Distribution
Unattended
12.50
4.00
30
5
67
894-HARPER
Distribution
Unattended
12.50
4.00
20
3
68
38-HUMBOLDT PARK-2
Distribution
Unattended
12.50
4.00
30
4
69
860-HYDE PARK
Distribution
Unattended
12.50
4.00
20
3
70
674-IRVING PARK
Distribution
Unattended
12.50
4.00
15
2
71
Z314-JUSTINE
Distribution
Unattended
12.50
4.00
15
2
72
793-LARAMIE
Distribution
Unattended
12.50
4.00
22
3
73
603-LAWRENCE
Distribution
Unattended
12.50
4.00
15
2
74
821-MARQUETTE PARK
Distribution
Unattended
12.50
4.00
22
3
75
895-MARSHFIELD
Distribution
Unattended
12.50
4.00
15
2
76
X313-MONTROSE
Distribution
Unattended
12.50
4.00
24
3
77
Z306-NARRAGANSETT
Distribution
Unattended
34.00
12.00
16
2
78
X312-NEWPORT
Distribution
Unattended
12.50
4.00
13
2
79
X315-NEVA #1
Distribution
Unattended
12.50
4.00
12
3
80
687-NORWOOD PARK
Distribution
Unattended
12.5
4
25
4
81
741-PERSHING
Distribution
Unattended
12.5
4
22
3
82
884-PRAIRIE
Distribution
Unattended
12.5
4
13
3
83
X307-ROSEMONT
Distribution
Unattended
34.0
4
15
2
84
626-SCHOOL
Distribution
Unattended
13
4
12
2
85
Z335-SOUTH CHICAGO
Distribution
Unattended
12.5
4
30
4
86
875-THROOP
Distribution
Unattended
12.5
4
18
3
87
X319-UPTOWN
Distribution
Unattended
12.5
4
24
3
88
851-WASHTENAW
Distribution
Unattended
12.5
4
23
3
89
691-WAVELAND
Distribution
Unattended
12.5
4
28
4
90
761-WENDELL
Distribution
Unattended
12.5
4
28
3
91
855-WINDSOR PARK
Distribution
Unattended
12.5
4
23
3
92
X380-WRIGHTWOOD
Distribution
Unattended
12.5
4
23
3
93
Y314-17TH STREET
Distribution
Unattended
12.5
4
23
3
94
Y302-27TH STREET
Distribution
Unattended
12.5
4
15
2
95
Y308-28TH STREET
Distribution
Unattended
12.5
4
23
3
96
871-56TH STREET
Distribution
Unattended
12.5
4
15
2
97
853-62ND STREET
Distribution
Unattended
12.5
4
15
2
98
896-111TH STREET
Distribution
Unattended
12.5
4
12
4
99
X318-MERRIMAC
Distribution
Unattended
12.5
4
11
3
100
CHICAGO (UNDER 10 MVA)
101
X315-NEVA #2
Distribution
Unattended
13
4
3
1
102
30-COLUMBUS PARK-2
Distribution
Unattended
12.5
4
6
1
103
Z302-EWING
Distribution
Unattended
12.5
4
8
2
104
32-HANSON PARK-2
Distribution
Unattended
12.5
4
4
1
105
Z305-KEATING
Distribution
Unattended
12.5
4
8
2
106
X311-LEHIGH
Distribution
Unattended
34
4
6
1
107
Z307-NEWCASTLE
Distribution
Unattended
34
12.5
9
1
108
X39-PORTAGE PARK
Distribution
Unattended
12.5
4
3
1
109
X368-SAUGANASH#1
Distribution
Unattended
12.5
4
3
1
110
X368-SAUGANASH#2
Distribution
Unattended
12.5
4
8
2
111
X305-SEMINARY
Distribution
Unattended
12.5
4
7
1
112
43-WILDWOOD-2
Distribution
Unattended
12.5
4
5
1
113
OUTSIDE CHICAGO (OVER 10MVA)
114
240-CARY
Distribution
Unattended
138
12.5
80
2
115
569-SUGAR GROVE-1
Distribution
Unattended
138
12.5
80
2
116
101-ITASCA
Distribution
Unattended
138.00
12.50
120
3
117
259-ALGONQUIN
Distribution
Unattended
138.00
12.50
120
3
118
552-ADDISON
Distribution
Unattended
138.00
12.50
73
2
119
160-ALPINE-1
Distribution
Unattended
138.00
12.50
106
3
120
160-ALPINE-2
Distribution
Unattended
138.00
69.00
50
1
121
60-ALSIP-1
Distribution
Unattended
138.00
12.50
146
4
122
60-ALSIP-2
Distribution
Unattended
138.00
34.00
12.50
80
2
123
230-ANTIOCH
Distribution
Unattended
138.00
12.50
80
2
124
109-APTAKISIC
Distribution
Unattended
138.00
12.50
160
4
125
487-ARCHER
Distribution
Unattended
138.00
12.50
80
2
126
268-ARLINGTON
Distribution
Unattended
138.00
12.50
160
4
127
233-BARRINGTON
Distribution
Unattended
138.00
12.50
80
4
128
250-BARRINGTON HILLS
Distribution
Unattended
138.00
12.50
12
1
129
574-BARTLETT
Distribution
Unattended
138.00
12.50
146
4
130
391-ARGYLE
Distribution
Unattended
138.00
12.50
60
2
131
115-BEDFORD PARK-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
132
115-BEDFORD PARK-2
Distribution
Unattended
138.00
34.00
12.50
180
5
133
64-BELLWOOD-1
Distribution
Unattended
138.00
12.50
106
3
134
64-BELLWOOD-2
Distribution
Unattended
138.00
34.00
12.50
240
4
135
416-BELL ROAD
Distribution
Unattended
138.00
12.50
146
4
136
122-BELVIDERE-1
Distribution
Unattended
138.00
34.00
12.50
120
2
137
122-BELVIDERE-2
Distribution
Unattended
138.00
12.50
80
2
138
549-BERKELEY
Distribution
Unattended
138.00
12.50
80
2
139
556-BERWYN-1
Distribution
Unattended
69.00
12.50
80
2
140
387-BLACKHAWK
Distribution
Unattended
138.00
12.50
40
2
141
179-BLOOM-1
Transmission
Unattended
345.00
138.00
34.00
300
1
142
179-BLOOM-2
Distribution
Unattended
138.00
12.50
73
2
143
76-BLUE ISLAND-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
144
76-BLUE ISLAND-2
Distribution
Unattended
138.00
34.00
12.50
120
3
145
76-BLUE ISLAND-3
Distribution
Unattended
138.00
12.50
100
3
146
561-BOLINGBROOK
Distribution
Unattended
138.00
12.50
160
4
147
70-BRADLEY-1
Distribution
Unattended
138.00
34.00
12.50
160
4
148
70-BRADLEY-2
Distribution
Unattended
138.00
12.50
146
4
149
531-BRIDGEVIEW
Distribution
Unattended
138.00
12.50
80
2
150
474-BRIGGS
Distribution
Unattended
138.00
12.50
80
2
151
J19-BRUCE ROAD
Distribution
Unattended
34.00
12.50
16
2
152
237-BUFFALO GROVE
Distribution
Unattended
138.00
12.50
80
2
153
177-BURNHAM
Transmission
Unattended
345.00
138.00
34.00
600
2
154
136-BURR RIDGE
Distribution
Unattended
138.00
12.50
160
4
155
152-BUSSE-1
Distribution
Unattended
138.00
34.00
12.50
120
2
156
152-BUSSE-2
Distribution
Unattended
138.00
12.50
160
4
157
557-BUTTERFIELD
Distribution
Unattended
138.00
12.50
80
2
158
433-CHANNAHON WEST-1
Distribution
Unattended
138.00
12.50
20
1
159
380-CHARLES
Distribution
Unattended
138.00
13.20
73
2
160
156-CHERRY VALLEY
Transmission
Unattended
345.00
138.00
34.00
900
3
161
73-CHICAGO HEIGHTS
Distribution
Unattended
138.00
34.00
12.50
180
3
162
568-CHURCH ROAD
Distribution
Unattended
138.00
12.50
80
2
163
59-CICERO-1
Distribution
Unattended
69.00
12.50
78
3
164
550-CLEARING
Distribution
Unattended
138.00
12.50
113
3
165
23-COLLINS
Transmission
Unattended
765.00
345.00
34.00
1000
3
166
435-COUNTRY CLUB HILLS
Distribution
Unattended
138.00
12.50
120
3
167
461-CRESTWOOD
Distribution
Unattended
138.00
12.50
160
4
168
75-CRYSTAL LAKE-1
Distribution
Unattended
138.00
34.00
12.50
120
3
169
75-CRYSTAL LAKE-2
Distribution
Unattended
138.00
12.50
136
4
170
86-DAVIS CREEK-1
Transmission
Unattended
345.00
138.00
34.00
900
3
171
86-DAVIS CREEK-2
Distribution
Unattended
138.00
12.50
40
1
172
213-DEERFIELD
Distribution
Unattended
138.00
12.50
160
4
173
521-BRISTOL TWP
Distribution
Unattended
138.00
12.50
80
2
174
240-CARY-2
Distribution
Unattended
138.00
12.50
80
2
175
46-DESPLAINES-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
176
46-DESPLAINES-2
Distribution
Unattended
138.00
34.00
12.50
120
2
177
46-DESPLAINES-3
Distribution
Unattended
138.00
12.50
120
3
178
198-DESPLAINES
Distribution
Unattended
138.00
12.50
139
4
179
107-DIXON
Distribution
Unattended
138.00
34.00
12.50
120
2
180
317-DIXON
Distribution
Unattended
138.00
12.50
50
2
181
580-DOWNERS GROVE
Distribution
Unattended
138.00
12.50
160
4
182
12-DRESDEN-1
Transmission
Unattended
345.00
138.00
34.00
600
2
183
12-DRESDEN-2
Distribution
Unattended
138.00
34.00
12.50
40
1
184
260-DUNDEE
Distribution
Unattended
138.00
12.50
80
2
185
66-EAST FRANKFORT
Transmission
Unattended
345.00
138.00
34.00
300
1
186
389-EAST ROCKFORD
Distribution
Unattended
138.00
12.50
80
2
187
111-ELECTRIC JUNCTION-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
188
111-ELECTRIC JUNCTION-2
Distribution
Unattended
138.00
12.50
80
2
189
111-ELECTRIC JUNCTION-3
Distribution
Unattended
138.00
34.00
12.50
120
2
190
370-ELEROY
Distribution
Unattended
138.00
12.50
40
2
191
570-ELGIN
Distribution
Unattended
138.00
12.50
160
4
192
135-ELMHURST-1
Transmission
Unattended
345.00
138.00
34.00
900
3
193
135-ELMHURST-2
Distribution
Unattended
138.00
12.50
80
2
194
258-ELMWOOD
Distribution
Unattended
138.00
12.50
80
2
195
47-EVANSTON-1
Distribution
Unattended
138.00
34.00
12.50
80
2
196
47-EVANSTON-2
Distribution
Unattended
138.00
12.50
160
4
197
433-CHANNAHON WEST-2
Distribution
Unattended
138.00
34.00
60
1
198
469-EVERGREEN
Distribution
Unattended
138.00
12.50
120
3
199
385-FIFTEENTH ST SUB
Distribution
Unattended
69.00
12.50
25
1
200
165-FORDHAM-1
Distribution
Unattended
138.00
12.50
50
1
201
165-FORDHAM-2
Distribution
Unattended
69.00
12.50
83
2
202
57-FOREST PARK
Distribution
Unattended
69.00
12.50
75
3
203
140-FRANKFORT
Distribution
Unattended
138.00
12.50
80
2
204
78-FRANKLIN PARK-1
Distribution
Unattended
138.00
34.00
12.50
240
4
205
78-FRANKLIN PARK-2
Distribution
Unattended
138.00
12.50
100
3
206
121-FREEPORT-1
Distribution
Unattended
138.00
34.00
12.50
80
2
207
121-FREEPORT-2
Distribution
Unattended
138.00
12.50
40
2
208
581-FRONTENAC
Distribution
Unattended
138.00
12.50
160
4
209
132-GARDEN PLAIN-1
Distribution
Unattended
138.00
34.00
12.50
80
3
210
572-GILBERTS
Distribution
Unattended
138.00
12.50
120
3
211
562-GLENDALE HTS
Distribution
Unattended
138.00
12.50
160
4
212
555-GLEN ELLYN
Distribution
Unattended
138.00
12.50
80
2
213
452-GLENWOOD
Distribution
Unattended
138.00
12.50
100
4
214
83-GLIDDEN-1
Distribution
Unattended
138.00
12.50
80
2
215
83-GLIDDEN-2
Distribution
Unattended
138.00
34.00
12.50
80
2
216
172-GOLF MILL-1
Transmission
Unattended
345.00
138.00
34.00
600
2
217
172-GOLF MILL-2
Distribution
Unattended
138.00
12.50
160
4
218
116-GOODINGS GROVE
Transmission
Unattended
345.00
138.00
34.00
1200
4
219
72-GOOSE LAKE
Distribution
Unattended
138.00
34.00
12.50
80
2
220
560-GRACE
Distribution
Unattended
138.00
12.50
80
2
221
458-GREEN LAKE
Distribution
Unattended
138.00
12.50
80
2
222
294-GURNEE
Distribution
Unattended
138.00
12.50
120
3
223
563-HANOVER TWP
Distribution
Unattended
138.00
12.50
80
2
224
388-HARLEM
Distribution
Unattended
138.00
12.50
100
2
225
384-HARRISON
Distribution
Unattended
69.00
12.50
80
2
226
443-HARVEY
Distribution
Unattended
138.00
12.50
80
2
227
52-HAWTHORNE
Distribution
Unattended
69.00
12.50
77
3
228
48-HIGHLAND PARK-1
Distribution
Unattended
138.00
34.00
12.50
120
3
229
48-HIGHLAND PARK-2
Distribution
Unattended
138.00
12.50
73
2
230
436-HILLCREST
Distribution
Unattended
138.00
12.50
160
4
231
214-HOFFMAN ESTATES
Distribution
Unattended
138.00
12.50
160
4
232
215-HOWARD
Distribution
Unattended
138.00
12.50
80
2
233
101-ITASCA-1
Transmission
Unattended
345.00
138.00
34.00
600
2
234
101-ITASCA-2
Distribution
Unattended
138.00
34.00
180
3
235
456-JOLIET CENTRAL
Distribution
Unattended
138.00
12.50
40
2
236
157-KANKAKEE
Distribution
Unattended
138.00
12.50
80
2
237
134-LAGRANGE PARK
Distribution
Unattended
138.00
12.50
120
3
238
222-LAKE BLUFF
Distribution
Unattended
138.00
12.50
80
2
239
234-LAKEHURST
Distribution
Unattended
138.00
12.50
147
4
240
225-LANDMEIER
Distribution
Unattended
138.00
12.50
80
2
241
446-LANSING
Distribution
Unattended
138.00
12.50
80
2
242
1-LASALLE
Transmission
Attended
345.00
138.00
34.00
300
1
243
166-LEITHTON-1
Distribution
Unattended
138.00
34.00
12.50
40
1
244
166-LEITHTON-2
Distribution
Unattended
138.00
12.50
160
4
245
180-LENA
Distribution
Unattended
138.00
34.00
12.50
80
2
246
154-LIBERTYVILLE-1
Transmission
Unattended
345.00
138.00
34.00
600
2
247
154-LIBERTYVILLE-2
Distribution
Unattended
138.00
12.50
106
3
248
103-LISLE-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
249
103-LISLE-2
Distribution
Unattended
138.00
34.00
12.50
120
3
250
103-LISLE-3
Distribution
Unattended
138.00
12.50
153
4
251
120-LOMBARD-1
Transmission
Attended
345.00
138.00
34.00
600
2
252
120-LOMBARD-2
Distribution
Attended
138.00
34.00
12.50
120
3
253
120-LOMBARD-3
Distribution
Attended
138.00
12.50
120
3
254
409-SOUTH JOLIET
Distribution
Unattended
138.00
34.00
180
3
255
248-LAKE ZURICH
Distribution
Unattended
138.00
12.50
120
3
256
123-MARENGO
Distribution
Unattended
138.00
34.00
12.50
160
4
257
124-MARYLAND
Distribution
Unattended
138.00
34.00
12.50
80
2
258
127-MATTESON-1
Distribution
Unattended
138.00
34.00
12.50
80
2
259
127-MATTESON-2
Distribution
Unattended
138.00
12.50
120
3
260
77-MAZON
Distribution
Unattended
138.00
34.00
12.50
80
2
261
51-MCCOOK-1
Transmission
Attended
345.00
138.00
34.00
600
2
262
51-MCCOOK-2
Distribution
Attended
138.00
34.00
12.50
180
3
263
51-MCCOOK-3
Distribution
Attended
138.00
12.50
120
3
264
193-MCHENRY-1
Distribution
Unattended
138.00
34.00
12.50
120
2
265
193-MCHENRY-2
Distribution
Unattended
138.00
34.00
106
3
266
139-MENDOTA
Distribution
Unattended
138.00
34.00
12.50
40
1
267
182-MINONK
Distribution
Unattended
138.00
34.00
12.50
40
1
268
451-MOKENA
Distribution
Unattended
138.00
12.50
160
4
269
106-MONTGOMERY-1
Distribution
Unattended
138.00
34.00
12.50
80
2
270
106-MONTGOMERY-2
Distribution
Unattended
138.00
12.50
80
2
271
216-MT PROSPECT
Distribution
Unattended
138.00
12.50
80
2
272
155-NELSON
Transmission
Unattended
345.00
138.00
34.00
900
3
273
406-NEW LENOX
Distribution
Unattended
138.00
12.50
120
3
274
129-NILES-1
Distribution
Unattended
138.00
34.00
12.50
120
2
275
129-NILES-2
Distribution
Unattended
138.00
12.50
120
3
276
565-NORDIC
Distribution
Unattended
138.00
12.50
80
2
277
125-NORMANDY
Distribution
Unattended
138.00
34.00
2.40
60
2
278
525-NORMANTOWN
Distribution
Unattended
138.00
12.50
80
2
279
56-NORTH AURORA-1
Distribution
Unattended
138.00
34.00
12.50
160
4
280
56-NORTH AURORA-2
Distribution
Unattended
138.00
12.50
140
4
281
159-NORTHBROOK
Transmission
Unattended
345.00
138.00
34.00
600
2
282
212-NORTHBROOK
Distribution
Unattended
138.00
12.50
160
4
283
69-NORTH CHICAGO-1
Distribution
Unattended
138.00
34.00
12.50
80
2
284
566-OAKBROOK
Distribution
Unattended
138.00
12.50
160
4
285
505-OAKPARK
Distribution
Unattended
138.00
12.50
120
3
286
204-OLD ELM
Distribution
Unattended
138.00
12.50
120
3
287
470-ORLAND
Distribution
Unattended
138.00
12.50
80
2
288
592-OSWEGO
Distribution
Unattended
138.00
12.50
120
3
289
102-PALATINE-1
Distribution
Unattended
138.00
34.00
12.50
80
2
290
102-PALATINE-2
Distribution
Unattended
138.00
12.50
160
4
291
440-PALOS
Distribution
Unattended
138.00
12.50
80
2
292
457-PARK FOREST
Distribution
Unattended
138.00
12.50
67
2
293
386-PECATONICA
Distribution
Unattended
138.00
12.50
10
1
294
162-PIERPONT-1
Distribution
Unattended
138.00
12.50
60
2
295
162-PIERPONT-2
Distribution
Unattended
69.00
12.50
25
1
296
221-NORTH HUNTLEY
Distribution
Unattended
138.00
12.50
80
2
297
454-PLAINFIELD
Distribution
Unattended
138.00
12.50
120
3
298
444-MINOOKA
Distribution
Unattended
138.00
12.50
80
2
299
167-PLANO-1
Transmission
Unattended
765.00
345.00
34.00
2000
6
300
167-PLANO-2
Transmission
Unattended
345.00
138.00
34.00
300
1
301
527-PLANO
Distribution
Unattended
138.00
34.00
60
1
302
595-PLEASANT HILL
Distribution
Unattended
138.00
12.50
160
4
303
141-PLEASANT VALLEY
Transmission
Unattended
345.00
138.00
34.00
300
1
304
80-PONTIAC MIDPOINT-1
Transmission
Unattended
345.00
138.00
34.00
450
2
305
80-PONTIAC MIDPOINT-2
Distribution
Unattended
138.00
34.00
12.50
180
3
306
235-POPLAR CREEK
Distribution
Unattended
138.00
12.50
80
2
307
117-PROSPECT HEIGHTS-1
Transmission
Unattended
345.00
138.00
34.00
600
2
308
117-PROSPECT HEIGHTS-2
Distribution
Unattended
138.00
12.50
120
3
309
217-PROSPECT HTS
Distribution
Unattended
138.00
12.50
80
2
310
192-RIDGELAND
Distribution
Unattended
138.00
69.00
12.50
600
6
311
414-ROBERTS ROAD
Distribution
Unattended
138.00
12.50
80
2
312
439-ROCKDALE
Distribution
Unattended
138.00
12.50
80
2
313
133-ROCK FALLS-1
Distribution
Unattended
138.00
34.00
12.50
80
2
314
206-ROLLING MEADOWS
Distribution
Unattended
138.00
12.50
160
4
315
411-ROMEOVILLE
Distribution
Unattended
138.00
12.50
80
2
316
163-ROSCOE BERT-1
Distribution
Unattended
138.00
69.00
12.50
50
1
317
163-ROSCOE BERT-2
Distribution
Unattended
138.00
12.50
120
3
318
42-ROUND LAKE-1
Distribution
Unattended
138.00
34.00
12.50
120
2
319
42-ROUND LAKE-2
Distribution
Unattended
138.00
12.50
80
2
320
251-ROUND LAKE BEACH
Distribution
Unattended
138.00
12.50
80
2
321
194-SABROOKE-1
Distribution
Attended
138.00
69.00
12.50
150
2
322
194-SABROOKE-2
Distribution
Attended
138.00
12.50
80
2
323
164-SAND PARK
Distribution
Unattended
138.00
12.50
80
2
324
447-SANDRIDGE
Distribution
Unattended
138.00
12.50
40
2
325
146-SANDWICH
Distribution
Unattended
138.00
34.00
12.50
80
2
326
517-SAYRE
Distribution
Unattended
138.00
12.50
80
2
327
220-SOUTH SCHAUMBURG
Distribution
Unattended
138.00
12.50
120
3
328
253-SCHAUMBURG
Distribution
Unattended
138.00
12.50
160
4
329
431-SHOREWOOD
Distribution
Unattended
138.00
12.50
160
4
330
138-SILVER LAKE
Transmission
Unattended
345.00
138.00
34.00
600
2
331
85-SKOKIE-1
Distribution
Unattended
138.00
34.00
12.50
120
3
332
85-SKOKIE-2
Distribution
Unattended
138.00
12.50
140
4
333
88-SKOKIE-1
Transmission
Unattended
345.00
138.00
34.00
1200
4
334
88-SKOKIE-2
Distribution
Unattended
138.00
34.00
12.50
120
3
335
88-SKOKIE-3
Distribution
Unattended
138.00
12.50
106
3
336
577-SOUTH ELGIN-1
Distribution
Unattended
138.00
12.50
80
2
337
465-SOUTH HOLLAND
Distribution
Unattended
138.00
12.50
120
3
338
577-SOUTH ELGIN-2
Distribution
Unattended
138.00
34.00
120
2
339
390-SOUTH PECATONICA
Distribution
Unattended
138.00
12.50
10
1
340
79-SPAULDING-1
Distribution
Unattended
138.00
34.00
12.50
160
3
341
79-SPAULDING-2
Distribution
Unattended
138.00
12.50
80
2
342
372-STERLING
Distribution
Unattended
138.00
12.50
60
2
343
176-STILLMAN VALLEY
Distribution
Unattended
138.00
34.00
12.50
80
2
344
61-STREATOR
Distribution
Unattended
138.00
34.00
12.50
80
2
345
569-SUGAR GROVE-2
Distribution
Unattended
138.00
34.00
12.50
60
1
346
419-TINLEY PARK
Distribution
Unattended
138.00
12.50
160
4
347
185-TOLLWAY
Transmission
Unattended
345.00
138.00
34.00
300
1
348
207-TONNE-1
Distribution
Unattended
138.00
12.50
160
4
349
207-TONNE-2
Distribution
Unattended
138.00
34.00
12.50
120
2
350
539-WARRENVILLE
Distribution
Unattended
138.00
12.50
120
3
351
113-WATERMAN
Distribution
Unattended
138.00
34.00
4.00
40
1
352
16-WAUKEGAN-1
Transmission
Unattended
345.00
138.00
34.00
600
2
353
16-WAUKEGAN-2
Distribution
Attended
138.00
34.00
12.50
160
4
354
16-WAUKEGAN-3
Distribution
Attended
138.00
12.50
40
2
355
144-WAYNE
Transmission
Unattended
345.00
138.00
34.00
600
2
356
499-WEBER
Distribution
Unattended
138.00
12.50
80
2
357
171-WEMPLETOWN
Transmission
Unattended
345.00
138.00
34.00
300
1
358
131-WEST CHICAGO-1
Distribution
Unattended
138.00
34.00
12.50
160
4
359
131-WEST CHICAGO-2
Distribution
Unattended
138.00
12.50
120
3
360
375-WEST DEKALB
Distribution
Unattended
138.00
12.50
80
2
361
205-WHEELING
Distribution
Unattended
138.00
12.50
80
2
362
18-WILL COUNTY
Distribution
Attended
138.00
34.00
12.50
120
2
363
593-WILLOW SPRINGS
Distribution
Unattended
138.00
12.50
80
2
364
149-WILMINGTON-1
Distribution
Unattended
138.00
34.00
12.00
120
3
365
480-VETERANS
Distribution
Unattended
138.00
12.50
80
2
366
149-WILMINGTON-2
Distribution
Unattended
138.00
12.50
40
1
367
228-WILSON ROAD
Distribution
Unattended
138.00
12.50
120
3
368
112-WILTON CENTER
Transmission
Unattended
765.00
345.00
34.00
2000
6
369
143-WOLFS CROSSING
Transmission
Unattended
345.00
138.00
34.00
300
1
370
453-WOODHILL
Distribution
Unattended
138.00
12.50
113
3
371
559-WOODRIDGE
Distribution
Unattended
138.00
12.50
80
2
372
151-WOODSTOCK
Distribution
Unattended
138.00
12.50
120
3
373
145-YORK CENTER
Distribution
Unattended
138.00
12.50
240
6
374
282 ZION
Distribution
Unattended
138.00
12.50
40
2
375
184-ELK GROVE
Distribution
Unattended
138.00
34.00
120
2
376
GENERAL WAREHOUSE
377
TECHNICAL CENTER
378
E28-ALGONQUIN
Distribution
Unattended
34.00
12.50
28
3
379
513-AURORA-1
Distribution
Unattended
34.00
12.50
31
4
380
513-AURORA-2
Distribution
Unattended
34.00
4.00
13
2
381
W16-AURORA (INDIAN TRAIL)
Distribution
Unattended
34.00
12.50
16
2
382
W73-BALD MOUND
Distribution
Unattended
34.00
12.50
18
2
383
115-BEDFORD PARK
Distribution
Unattended
34.00
12.50
16
2
384
64-BELLWOOD
Distribution
Unattended
34.00
4.00
11
2
385
B20-BELVIDERE
Distribution
Unattended
34.00
12.50
28
3
386
556-BERWYN-2
Distribution
Unattended
12.50
4.00
16
2
387
W26-BIG TIMBER
Distribution
Unattended
34.00
12.50
28
3
388
W16-BLACKBERRY TWP
Distribution
Unattended
34.00
12.50
16
2
389
J69-BRAIDWOOD
Distribution
Unattended
34.00
12.50
25
3
390
W119-BRISTOL TWP
Distribution
Unattended
34.00
12.50
16
2
391
E24-CARY
Distribution
Unattended
34.00
12.50
19
2
392
K19-CEMETARY RD
Distribution
Unattended
34.00
12.50
22
3
393
B31-CHEMUNG
Distribution
Unattended
34.00
12.50
16
2
394
F96-CHICAGO HEIGHTS
Distribution
Unattended
34.00
12.50
12
2
395
59-CICERO-2
Distribution
Unattended
12.50
4.00
20
2
396
S37-BRUCE TWP
Distribution
Unattended
34.00
12.50
12
2
397
W384-BUTTERFIELD-1
Distribution
Unattended
34.00
12.50
10
1
398
B29-BYRON
Distribution
Unattended
34.00
12.50
25
3
399
J68-COAL CITY
Distribution
Unattended
34.00
12.50
19
2
400
F45-CRETE
Distribution
Unattended
34.00
12.50
19
2
401
E77-CRYSTAL LAKE
Distribution
Unattended
34.00
12.50
28
3
402
W50-DEERPATH
Distribution
Unattended
34.00
12.50
25
3
403
H78-DIXON
Distribution
Unattended
34.00
12.50
12
2
404
E71-DORR TWP-1
Distribution
Unattended
34.00
12.50
16
2
405
W38-DOWNERS GROVE TW
Distribution
Unattended
34.00
12.50
19
2
406
A94-DRUCE LAKE
Distribution
Unattended
34.00
12.50
16
2
407
462-DWIGHT
Distribution
Unattended
34.00
12.50
18
2
408
J40 - WESTERN AVE
Distribution
Unattended
34.00
12.50
18
2
409
J46-KAVANAUGH
Distribution
Unattended
34.00
12.50
18
2
410
A71-GRASS LAKE
Distribution
Unattended
34.00
12.50
22
3
411
B12-CAPRON
Distribution
Unattended
34.00
12.00
16
2
412
J15-ELWOOD
Distribution
Unattended
34.00
12.50
19
2
413
C20-EVANSTON
Distribution
Unattended
34.00
12.50
16
2
414
B32-GARDEN PRAIRIE
Distribution
Unattended
34.00
12.50
19
2
415
J49-GOUGAR ROAD
Distribution
Unattended
34.00
12.50
18
2
416
C93-HIGHLAND PARK
Distribution
Unattended
34.00
4.00
11
2
417
W48-HINSDALE
Distribution
Unattended
34.00
12.50
18
2
418
J97-JACKSON ST. (JOLIET)
Distribution
Unattended
34.00
4.00
12
2
419
W118-KENDALL TWP
Distribution
Unattended
34.00
12.50
18
2
420
B15-KINGSTON
Distribution
Unattended
34.00
12.50
11
2
421
B52-LEAF RIVER
Distribution
Unattended
34.00
12.50
15
4
422
H52-LELAND
Distribution
Unattended
34.00
12.50
12
2
423
W20-LILY LAKE
Distribution
Unattended
34.00
12.50
19
2
424
J58-MANHATTAN
Distribution
Unattended
34.00
12.50
16
2
425
B90-MAPLE PARK
Distribution
Unattended
34.00
12.50
16
2
426
123-MARGENGO
Distribution
Unattended
34.00
12.50
19
2
427
W35-UDINA
Distribution
Unattended
34.00
12.50
19
2
428
B10-HARVARD
Distribution
Unattended
34.00
12.50
16
2
429
318-HARVARD
Distribution
Unattended
34.00
12.50
19
2
430
460-HARVEY-1
Distribution
Unattended
34.00
12.50
20
2
431
460-HARVEY-2
Distribution
Unattended
34.00
4.00
20
2
432
C3-HIGHLAND PARK-1
Distribution
Unattended
34.00
12.50
18
2
433
D62-HILLSIDE
Distribution
Unattended
34.00
12.50
19
2
434
H47-HINCKLEY
Distribution
Unattended
34.00
12.50
12
2
435
553-HINSDALE
Distribution
Unattended
34.00
12.50
13
2
436
C65-EVANSTON
Distribution
Unattended
34.00
4.00
12
2
437
C66-EVANSTON
Distribution
Unattended
34.00
12.50
18
2
438
A31-FOX LAKE
Distribution
Unattended
34.00
12.50
19
3
439
W10-FOX RIVER HEIGHTS
Distribution
Unattended
34.00
12.50
19
2
440
D13-FORESTVIEW
Distribution
Unattended
34.00
12.50
16
2
441
121-FREEPORT
Distribution
Unattended
34.00
4.00
19
2
442
H23-FULTON
Distribution
Unattended
34.00
12.50
12
2
443
514-GLEN ELLYN
Distribution
Unattended
34.00
4.00
12
2
444
W115-GLENWOOD PARK
Distribution
Unattended
34.00
12.50
19
2
445
A87-GRAYS LAKE
Distribution
Unattended
34.00
12.50
19
2
446
B16-HAMPSHIRE
Distribution
Unattended
34.00
12.50
28
3
447
D351-HODGINS
Distribution
Unattended
34.00
12.50
16
2
448
E18-HONEY LAKE
Distribution
Unattended
34.00
12.50
19
2
449
E35-HUNTLEY
Distribution
Unattended
34.00
12.50
19
2
450
E29-JOHNSBURG
Distribution
Unattended
34.00
12.50
28
2
451
E19-ISLAND LAKE
Distribution
Unattended
34.00
12.50
19
2
452
450-WASHINGTON ST. JOLIET
Distribution
Unattended
34.00
12.50
19
2
453
LAGRANGE
454
280-LAKE BLUFF
Distribution
Unattended
34.00
4.00
13
3
455
C30-LAKE FOREST
Distribution
Unattended
34.00
12.50
19
2
456
E26-LAKE IN THE HILLS
Distribution
Unattended
34.00
12.50
28
3
457
A47-LAKE VILLA
Distribution
Unattended
34.00
12.50
19
2
458
K34-LEHIGH
Distribution
Unattended
34.00
12.50
16
2
459
J92-LEMONT
Distribution
Unattended
34.00
12.50
12
2
460
A12-LIBERTYVILLE
Distribution
Unattended
34.00
12.50
18
2
461
C81-LINCOLNWOOD
Distribution
Unattended
34.00
4.00
12
2
462
F149-LYNWOOD
Distribution
Unattended
34.00
12.50
13
2
463
K20-MANTENO
Distribution
Unattended
34.00
12.50
18
2
464
B51-MARENGO
Distribution
Unattended
34.00
12.50
16
2
465
D53-MAYWOOD
Distribution
Unattended
12.50
4.00
13
2
466
D187-MAYWOOD-1
Distribution
Unattended
34.00
12.50
16
2
467
H39-MENDOTA
Distribution
Unattended
34.00
12.50
25
3
468
E16-MCHENRY
Distribution
Unattended
34.00
12.50
19
2
469
W336-MILTON TWP
Distribution
Unattended
34.00
12.50
19
2
470
K18-MOMENCE
Distribution
Unattended
34.00
12.50
19
2
471
422-MORRIS
Distribution
Unattended
34.00
12.50
18
2
472
H26-MORRISON
Distribution
Unattended
34.00
12.50
12
2
473
B30-MT MORRIS
Distribution
Unattended
34.00
12.50
16
2
474
E8-NERGE
Distribution
Unattended
34.00
12.50
16
2
475
W71-NORTH AURORA
Distribution
Unattended
34.00
12.50
19
2
476
69-NORTH CHICAGO-2
Distribution
Unattended
34.00
12.50
19
2
477
A24-NORTH CHICAGO
Distribution
Unattended
34.00
12.50
19
2
478
D46-NORTHLAKE
Distribution
Unattended
34.00
12.50
19
2
479
D177-O'HARE FIELD
Distribution
Unattended
34.00
12.50
13
2
480
D179-O'HARE FIELD
Distribution
Unattended
34.00
12.50
19
3
481
D180-O'HARE FIELD
Distribution
Unattended
34.00
12.50
22
3
482
505-OAK PARK
Distribution
Unattended
12.50
4.00
18
3
483
S43-ODELL
Distribution
Unattended
34.00
12.50
16
2
484
W18-ORCHARD RD
Distribution
Unattended
34.00
12.50
16
2
485
B53-OREGON
Distribution
Unattended
34.00
12.50
18
2
486
E12-PALATINE
Distribution
Unattended
34.00
12.50
19
2
487
C55-PARK RIDGE
Distribution
Unattended
34.00
4.00
13
2
488
F17-PEOTONE
Distribution
Unattended
34.00
12.50
19
2
489
W25-PINGREE GROVE
Distribution
Unattended
34.00
12.50
16
2
490
J31-PLAINFIELD
Distribution
Unattended
34.00
12.50
19
2
491
H65-PLANO
Distribution
Unattended
34.00
12.50
17
2
492
W211-PLATO CENTER
Distribution
Unattended
34.00
12.50
16
2
493
B36-POLO
Distribution
Unattended
34.00
12.50
16
2
494
S66-PONTIAC-1
Distribution
Unattended
34.00
12.50
16
2
495
471-PONTIAC
Distribution
Unattended
34.00
12.50
19
2
496
B11-POPLAR GROVE
Distribution
Unattended
34.00
12.50
19
2
497
W51-RANDALL ROAD
Distribution
Unattended
34.00
12.50
25
3
498
E82-RICHMOND
Distribution
Unattended
34.00
12.50
19
2
499
J28-RIDGE ROAD
Distribution
Unattended
34.00
12.50
18
2
500
B55-ROCK CITY
Distribution
Unattended
34.00
12.50
13
2
501
E69-ROLLING MEADOWS
Distribution
Unattended
34.00
12.50
28
3
502
A67-RONDOUT
Distribution
Unattended
34.00
12.50
25
3
503
W236-ROSELLE
Distribution
Unattended
34.00
12.50
19
2
504
H60-SANDWICH
Distribution
Unattended
34.00
12.50
16
2
505
H14-SANDWICH
Distribution
Unattended
34.00
12.50
28
3
506
F12-SAUK TRAIL
Distribution
Unattended
34.00
12.50
19
2
507
D63-SCHILLER PARK
Distribution
Unattended
34.00
12.50
25
3
508
C77-SKOKIE
Distribution
Unattended
34.00
4.00
13
2
509
85-SKOKIE
Distribution
Unattended
34.00
4.00
11
2
510
88-SKOKIE
Distribution
Unattended
34.00
4.00
13
2
511
H53-SOMONAUK
Distribution
Unattended
34.00
12.50
19
2
512
E79-SOUTH WONDERLAKE
Distribution
Unattended
34.00
12.50
16
2
513
E20-SPRING GROVE
Distribution
Unattended
34.00
12.50
28
3
514
H25-STERLING
Distribution
Unattended
34.00
12.50
16
2
515
S61-STREATOR
Distribution
Unattended
34.00
4.00
13
2
516
S44-STREATOR
Distribution
Unattended
34.00
12.50
16
2
517
H70-SUBLETTE
Distribution
Unattended
34.00
12.50
14
2
518
D40-SUMMIT
Distribution
Unattended
34.00
12.50
16
2
519
316-SYCAMORE
Distribution
Unattended
34.00
12.50
44
5
520
J17-TROY TWP
Distribution
Unattended
34.00
12.50
19
2
521
459-VOLLMER ROAD-1
Distribution
Unattended
34.00
12.50
25
4
522
W39-WASCO
Distribution
Unattended
34.00
12.50
28
3
523
E11-WAUCONDA
Distribution
Unattended
34.00
12.50
25
3
524
E22-WAUCONDA
Distribution
Unattended
34.00
12.50
25
3
525
A41-WAUKEGAN-2
Distribution
Unattended
34.00
4.00
13
2
526
A68-WAUKEGAN
Distribution
Unattended
34.00
12.50
16
2
527
A70-WAUKEGAN
Distribution
Unattended
34.00
12.50
25
3
528
W33-WAYNE
Distribution
Unattended
34.00
12.50
19
2
529
558-WESTMONT-1
Distribution
Unattended
34.00
12.50
31
4
530
W30-WHEATON
Distribution
Unattended
34.00
12.50
19
2
531
249-WILMETTE-1
Distribution
Unattended
34.00
12.50
34
4
532
249-WILMETTE-2
Distribution
Unattended
34.00
4.00
16
2
533
B95-SOUTH DEKALB
Distribution
Unattended
34.00
12.50
18
2
534
W29-WINFIELD TWP
Distribution
Unattended
34.00
12.50
13
2
535
E17-WONDER LAKE
Distribution
Unattended
34.00
12.50
16
2
536
G78-WORTH
Distribution
Unattended
34.00
12.50
16
2
537
A82-ZION
Distribution
Unattended
34.00
12.50
13
2
538
C23-SEARLE
Distribution
Unattended
34.00
12.50
19
2
539
A91-ZION
Distribution
Unattended
34.00
12.50
16
2
540
J25- JACKSON TWP.
Distribution
Unattended
34.00
12.50
18
2
541
W148-AURORA TWP
Distribution
Unattended
34.00
12.50
16
2
542
OUTSIDE CHICAGO (UNDER 10MVA)
543
W348-BENSENVILLE-1
Distribution
Unattended
34.00
12.50
9
1
544
W348-BENSENVILLE-2
Distribution
Unattended
34.00
4.00
3
1
545
D69-BROADVIEW-1
Distribution
Unattended
34.00
12.50
6
1
546
D69-BROADVIEW-2
Distribution
Unattended
34.00
4.00
5
1
547
W218-CARPENTERSVILLE-1
Distribution
Unattended
34.00
12.50
9
1
548
W218-CARPENTERSVILLE-2
Distribution
Unattended
34.00
4.00
5
1
549
E71-DORR TWP-2
Distribution
Unattended
34.00
4.00
3
1
550
B45-LENA
Distribution
Unattended
34.00
12.50
6
1
551
J16-EASTERN AVE (JOLIET)-1
Distribution
Unattended
34.00
12.50
6
1
552
J16-EASTERN AVE (JOLIET)-2
Distribution
Unattended
34.00
4.00
6
1
553
501-ELMHURST-1
Distribution
Unattended
34.00
12.50
6
1
554
501-ELMHURST-2
Distribution
Unattended
34.00
4.00
8
2
555
W345-ELMHURST-1
Distribution
Unattended
34.00
12.50
9
1
556
W345-ELMHURST-2
Distribution
Unattended
34.00
4.00
6
1
557
C53-EVANSTON-1
Distribution
Unattended
34.00
12.50
9
1
558
C53-EVANSTON-2
Distribution
Unattended
34.00
4.00
6
1
559
D99-FRANKLIN PARK-1
Distribution
Unattended
34.00
12.50
6
1
560
D99-FRANKLIN PARK-2
Distribution
Unattended
34.00
4.00
6
1
561
B17-GENOA-1
Distribution
Unattended
34.00
12.50
9
1
562
B17-GENOA-2
Distribution
Unattended
34.00
4.00
3
1
563
C62-GLENCOE-1
Distribution
Unattended
34.00
4.00
5
1
564
C62-GLENCOE-2
Distribution
Unattended
12.50
4.00
6
1
565
C3-HIGHLAND PARK-2
Distribution
Unattended
34.00
4.00
3
1
566
G88-HOMETOWN-1
Distribution
Unattended
34.00
12.50
6
1
567
G88-HOMETOWN-2
Distribution
Unattended
34.00
4.00
6
1
568
D16-LAGRANGE HIGHLANDS-1
Distribution
Unattended
34.00
12.50
9
1
569
D16-LAGRANGE HIGHLANDS-2
Distribution
Unattended
34.00
4.00
6
1
570
D87-LEYDEN TWP-1
Distribution
Unattended
34.00
12.50
9
1
571
D87-LEYDEN TWP-2
Distribution
Unattended
34.00
4.00
6
1
572
D 229-LYONS TWP-1
Distribution
Unattended
34.00
12.50
6
1
573
D 229-LYONS TWP-2
Distribution
Unattended
34.00
4.00
6
1
574
D187-MAYWOOD-2
Distribution
Unattended
34.00
4.00
6
1
575
D20-MELROSE PARK-1
Distribution
Unattended
34.00
12.50
9
1
576
D20-MELROSE PARK-2
Distribution
Unattended
34.00
4.00
9
1
577
311-MENDOTA-1
Distribution
Unattended
34.00
12.50
6
1
578
311-MENDOTA-2
Distribution
Unattended
34.00
4.00
9
2
579
C33-NILES-1
Distribution
Unattended
34.00
12.50
6
1
580
C33-NILES-2
Distribution
Unattended
34.00
4.00
6
1
581
C19-PARK RIDGE-1
Distribution
Unattended
34.00
4.00
5
3
582
C19-PARK RIDGE-2
Distribution
Unattended
34.00
12.50
9
1
583
S66-PONTIAC-2
Distribution
Unattended
34.00
4.00
8
2
584
D133-RIVER GROVE-1
Distribution
Unattended
34.00
12.50
9
1
585
D133-RIVER GROVE-2
Distribution
Unattended
34.00
4.00
5
1
586
D175-SCHILLER PARK-1
Distribution
Unattended
34.00
4.00
6
1
587
D175-SCHILLER PARK-2
Distribution
Unattended
34.00
12.50
9
1
588
J12-BREEN ROAD
Distribution
Unattended
34.00
12.50
9
1
589
H62-STERLING-1
Distribution
Unattended
34.00
12.50
6
1
590
H62-STERLING-2
Distribution
Unattended
34.00
4.00
5
1
591
C73-TECHNY-1
Distribution
Unattended
34.00
12.50
9
1
592
C73-TECHNY-2
Distribution
Unattended
34.00
4.00
3
1
593
C96-TECHNY SOUTH
Distribution
Unattended
34.00
12.50
9
1
594
W334-VILLA PARK-1
Distribution
Unattended
34.00
12.50
6
1
595
W334-VILLA PARK-2
Distribution
Unattended
34.00
4.00
6
1
596
459-VOLLMER ROAD-2
Distribution
Unattended
34.00
4.00
3
1
597
A41-WAUKEGAN-1
Distribution
Unattended
34.00
12.50
6
1
598
A43-WAUKEGAN-1
Distribution
Unattended
34.00
12.50
6
1
599
A43-WAUKEGAN-2
Distribution
Unattended
34.00
4.00
9
1
600
B49-KENT
Distribution
Unattended
34.00
12.50
9
1
601
G42-WORTH-1
Distribution
Unattended
34.00
12.50
9
1
602
G42-WORTH-2
Distribution
Unattended
34.00
4.00
3
1
603
558-WESTMONT-2
Distribution
Unattended
34.00
4.00
6
1
604
R19-ACORN
Distribution
Unattended
12.50
4.00
5
1
605
W346-ADDISON TWP
Distribution
Unattended
34.00
12.50
6
1
606
B89-AFTON
Distribution
Unattended
34.00
12.50
5
1
607
H67-AMBOY
Distribution
Unattended
34.00
12.50
6
1
608
H43-AMBOY (GREEN RIVER)
Distribution
Unattended
34.00
12.50
6
1
609
E27-ARLINGTON HEIGHTS
Distribution
Unattended
34.00
4.00
3
1
610
E39-ARLINGTON HEIGHTS
Distribution
Unattended
34.00
4.00
3
1
611
E70-ARLINGTON HEIGHTS
Distribution
Unattended
34.00
4.00
5
1
612
E81-ARLINGTON HEIGHTS
Distribution
Unattended
34.00
4.00
6
1
613
K32-AROMA PARK
Distribution
Unattended
34.00
12.50
6
1
614
H49-ASHTON
Distribution
Unattended
34.00
12.50
6
1
615
W114-AURORA (ILLINOIS AVE)
Distribution
Unattended
34.00
4.00
3
1
616
W148-AURORA TWP-1
Distribution
Unattended
34.00
12.50
16
2
617
W152-AURORA (KENSINGTON)
Distribution
Unattended
34.00
12.50
6
1
618
J21-AUX SABLE TWP
Distribution
Unattended
34.00
12.50
9
1
619
B39-BAILEYVILLE
Distribution
Unattended
34.00
12.50
9
1
620
W233-BARTLETT
Distribution
Unattended
34.00
12.50
9
1
621
A57-BEACH
Distribution
Unattended
34.00
12.50
6
1
622
R23-BEATTIE
Distribution
Unattended
12.50
4.00
5
1
623
F16-BEECHER
Distribution
Unattended
34.00
12.50
9
1
624
J81-BELLE AV
Distribution
Unattended
34.00
4.00
3
1
625
D12-BELLWOOD
Distribution
Unattended
34.00
4.00
6
1
626
B19-BELVIDERE-1
Distribution
Unattended
34.00
4.00
5
1
627
W349-BENSENVILLE
Distribution
Unattended
34.00
4.00
6
2
628
D86-BERKELEY
Distribution
Unattended
34.00
4.00
6
1
629
D34-BERWYN
Distribution
Unattended
12.50
4.00
6
1
630
S26-BLACKSTONE
Distribution
Unattended
34.00
12.50
3
1
631
J53-BLODGETT RD
Distribution
Unattended
34.00
12.50
9
1
632
F122-BLOOM TWP-1
Distribution
Unattended
34.00
12.50
9
1
633
F122-BLOOM TWP-2
Distribution
Unattended
34.00
4.00
3
1
634
F79-BLOOM TWP
Distribution
Unattended
34.00
4.00
9
1
635
G16-BLUE ISLAND
Distribution
Unattended
34.00
4.00
8
1
636
G64-BLUE ISLAND
Distribution
Unattended
34.00
4.00
3
1
637
G81-BLUE ISLAND
Distribution
Unattended
34.00
4.00
3
1
638
B19-BELVIDERE-2
Distribution
Unattended
34.00
12.50
9
1
639
J88-BLUFF ST (JOLIET)
Distribution
Unattended
34.00
4.00
5
1
640
K40-BOURBONNAIS TWP
Distribution
Unattended
34.00
12.50
9
1
641
K29-BRADLEY
Distribution
Unattended
34.00
4.00
5
1
642
C34-BRAESIDE
Distribution
Unattended
34.00
12.50
6
1
643
D242-BRIDGEVIEW
Distribution
Unattended
34.00
12.50
6
1
644
D47-BROADVIEW-1
Distribution
Unattended
34.00
12.50
6
1
645
D47-BROADVIEW-2
Distribution
Unattended
34.00
4.00
3
1
646
D80-BROADVIEW
Distribution
Unattended
34.00
12.50
9
1
647
J55-BROADWAY ST
Distribution
Unattended
34.00
4.00
3
1
648
D115-BROOKFIELD
Distribution
Unattended
34.00
4.00
6
1
649
D140-BROOKFIELD
Distribution
Unattended
34.00
4.00
6
1
650
E46-BURTON BRIDGE
Distribution
Unattended
34.00
12.50
9
1
651
G30-CALUMET CITY
Distribution
Unattended
34.00
4.00
3
1
652
G100-CALUMET CITY
Distribution
Unattended
34.00
4.00
5
1
653
B47-CEDARVILLE
Distribution
Unattended
34.00
12.50
6
1
654
D11-CENTERPOINT
Distribution
Unattended
34.00
12.50
9
1
655
J67-CHANNAHON
Distribution
Unattended
34.00
12.50
3
1
656
B50-CHERRY GROVE
Distribution
Unattended
34.00
12.50
8
1
657
J84-CHERRY ST (JOLIET)
Distribution
Unattended
34.00
4.00
5
1
658
F91-CHICAGO HEIGHTS
Distribution
Unattended
34.00
4.00
3
1
659
F73-CHICAGO HEIGHTS
Distribution
Unattended
34.00
12.50
6
1
660
D15-CICERO
Distribution
Unattended
12.50
4.00
7
1
661
D100-CICERO
Distribution
Unattended
12.50
4.00
6
1
662
D151-CICERO
Distribution
Unattended
12.50
4.00
6
1
663
D217-CICERO
Distribution
Unattended
12.50
4.00
5
1
664
B86-CLARE
Distribution
Unattended
34.00
12.50
6
1
665
B35-COLETA
Distribution
Unattended
34.00
12.50
5
1
666
S42-CORNELL
Distribution
Unattended
34.00
12.50
3
1
667
D44-COUNTRYSIDE
Distribution
Unattended
34.00
12.50
9
1
668
B26-DAVIS JUNCTION
Distribution
Unattended
34.00
12.50
9
1
669
H51-INDIAN CREEK
Distribution
Unattended
34.00
12.50
9
1
670
J48-BRANDON ROAD
Distribution
Unattended
34.00
12.50
9
1
671
C51-DESPLAINES
Distribution
Unattended
34.00
4.00
6
1
672
C79-DESPLAINES
Distribution
Unattended
34.00
4.00
6
1
673
G126-DOLTON
Distribution
Unattended
34.00
4.00
6
1
674
W41-DOWNERS GROVE
Distribution
Unattended
34.00
12.50
9
1
675
G909-DOLTON-1
Distribution
Unattended
34.00
12.50
9
1
676
G909-DOLTON-2
Distribution
Unattended
34.00
12.50
9
1
677
W384-BUTTERFIELD-2
Distribution
Unattended
34.00
12.50
9
1
678
W43-DOWNERS GROVE
Distribution
Unattended
34.00
4.00
6
1
679
J76-DUPONT RD
Distribution
Unattended
34.00
12.50
9
1
680
H50-EARLVILLE
Distribution
Unattended
34.00
12.50
6
1
681
K42-EAST KANKAKEE
Distribution
Unattended
34.00
12.50
6
1
682
B54-EAST OREGON
Distribution
Unattended
34.00
12.50
6
1
683
S48-EAST STREATOR
Distribution
Unattended
34.00
12.50
9
1
684
R26-EIGHTEENTH AVE
Distribution
Unattended
12.50
4.00
5
1
685
W13-ELDAMAIN
Distribution
Unattended
34.00
12.50
9
1
686
W202-ELGIN
Distribution
Unattended
34.00
12.50
9
1
687
W209-ELGIN
Distribution
Unattended
34.00
4.00
5
1
688
W342-ELMHURST
Distribution
Unattended
34.00
4.00
6
1
689
W343-ELMHURST-1
Distribution
Unattended
34.00
12.50
6
1
690
W343-ELMHURST-2
Distribution
Unattended
34.00
4.00
3
1
691
D111-ELMWOOD PARK
Distribution
Unattended
12.50
4.00
6
1
692
D149-ELMWOOD PARK
Distribution
Unattended
12.50
4.00
6
1
693
D173-ELMWOOD PARK
Distribution
Unattended
12.50
4.00
7
1
694
S41-EPPARDS POINT
Distribution
Unattended
34.00
12.50
4
1
695
C41-EVANSTON
Distribution
Unattended
34.00
4.00
9
1
696
C43-EVANSTON
Distribution
Unattended
34.00
4.00
6
1
697
C54-EVANSTON
Distribution
Unattended
34.00
12.50
9
1
698
C75-EVANSTON
Distribution
Unattended
34.00
4.00
6
1
699
C83-EVANSTON
Distribution
Unattended
34.00
12.50
9
1
700
G69-EVERGREEN PARK
Distribution
Unattended
34.00
4.00
6
1
701
G82-EVERGREEN PARK
Distribution
Unattended
34.00
4.00
6
1
702
K39-EXLINE ROAD
Distribution
Unattended
34.00
12.50
6
1
703
W102-FABYAN
Distribution
Unattended
34.00
12.50
6
1
704
D255-FORESTVIEW
Distribution
Unattended
34.00
12.50
9
1
705
B37-FORRESTON
Distribution
Unattended
34.00
12.50
5
1
706
R35-FOURTEENTH ST.
Distribution
Unattended
12.50
4.00
5
1
707
R24-FOURTH AVE.
Distribution
Unattended
34.00
4.00
5
1
708
E72-FOX RIVER GROVE
Distribution
Unattended
34.00
4.00
9
1
709
B64-FRANKLIN GROVE
Distribution
Unattended
34.00
12.50
6
1
710
B56-FREEPORT
Distribution
Unattended
34.00
4.00
3
1
711
A50-GAGES LAKE
Distribution
Unattended
34.00
12.50
6
1
712
H27-GALT
Distribution
Unattended
34.00
12.50
6
1
713
132-GARDEN PLAIN-2
Distribution
Unattended
34.00
12.50
6
1
714
S63-GARDNER
Distribution
Unattended
34.00
12.50
9
1
715
C61-GARNETT
Distribution
Unattended
34.00
12.50
9
1
716
W330-GLEN ELLYN
Distribution
Unattended
34.00
4.00
3
1
717
C92-GLENCOE
Distribution
Unattended
34.00
4.00
5
1
718
C7-GLENVIEW
Distribution
Unattended
34.00
4.00
5
1
719
C25-GLENVIEW
Distribution
Unattended
34.00
12.50
9
1
720
C80-GLENVIEW
Distribution
Unattended
34.00
12.50
9
1
721
C95-GLENVIEW
Distribution
Unattended
34.00
4.00
6
1
722
F36-GOODENOW
Distribution
Unattended
34.00
12.50
9
1
723
J66-GOOSE LAKE
Distribution
Unattended
34.00
12.50
6
1
724
S25-GRAND RAPIDS
Distribution
Unattended
34.00
12.50
6
1
725
S29-GRAND RIDGE
Distribution
Unattended
34.00
12.50
6
1
726
K44-GRANT PARK
Distribution
Unattended
34.00
12.50
6
1
727
A81-GREAT LAKES
Distribution
Unattended
34.00
12.50
6
1
728
E59-HAEGER'S CORNER
Distribution
Unattended
34.00
12.50
9
1
729
E21-HARTLAND
Distribution
Unattended
34.00
12.50
6
1
730
B14-HARVARD
Distribution
Unattended
34.00
4.00
3
1
731
G83-HARVEY
Distribution
Unattended
34.00
4.00
3
1
732
G113-HARVEY
Distribution
Unattended
34.00
4.00
6
1
733
B23-HERBERT
Distribution
Unattended
34.00
4.00
1
1
734
C82-HIGHLAND PARK
Distribution
Unattended
34.00
4.00
5
1
735
J62-HOMER TWP
Distribution
Unattended
34.00
12.50
9
1
736
F24-HOMEWOOD
Distribution
Unattended
34.00
4.00
6
2
737
F75-HOMEWOOD
Distribution
Unattended
34.00
4.00
3
1
738
H38-HOOPHOLE
Distribution
Unattended
34.00
12.50
4
1
739
J32-KAHLER RD
Distribution
Unattended
34.00
12.50
6
1
740
K23-KANKAKEE
Distribution
Unattended
34.00
4.00
4
1
741
K33-KANKAKEE
Distribution
Unattended
34.00
12.50
6
1
742
S14-KERNAN
Distribution
Unattended
34.00
12.50
1
1
743
B40-KETCHUM
Distribution
Unattended
34.00
12.50
9
1
744
B28-KIRKLAND
Distribution
Unattended
34.00
12.50
6
2
745
D172-LAGRANGE
Distribution
Unattended
34.00
4.00
6
1
746
D125-LAGRANGE PARK
Distribution
Unattended
34.00
4.00
6
1
747
C76-LAKE FOREST
Distribution
Unattended
34.00
4.00
6
2
748
B63-LANARK
Distribution
Unattended
34.00
12.50
9
1
749
H57-LEE
Distribution
Unattended
34.00
12.50
3
1
750
J87-LEMONT
Distribution
Unattended
34.00
12.50
9
1
751
D45-LEYDEN TWP
Distribution
Unattended
34.00
4.00
6
1
752
D67-LEYDEN TWP
Distribution
Unattended
34.00
12.50
6
1
753
D267-LEYDEN TWP
Distribution
Unattended
34.00
4.00
6
1
754
A64-LIBERTYVILLE
Distribution
Unattended
34.00
4.00
3
1
755
C22-LINCOLNWOOD
Distribution
Unattended
34.00
4.00
9
2
756
J24-LISBON
Distribution
Unattended
34.00
12.50
6
1
757
W44-LISLE
Distribution
Unattended
34.00
12.50
6
1
758
J18-LOCKPORT
Distribution
Unattended
34.00
12.50
9
1
759
S40-LODEMIA
Distribution
Unattended
34.00
12.50
3
1
760
120-LOMBARD
Distribution
Unattended
34.00
12.50
3
1
761
W52-LOMBARD
Distribution
Unattended
34.00
4.00
5
3
762
W331-LOMBARD
Distribution
Unattended
34.00
4.00
3
1
763
S21-LOSTANT
Distribution
Unattended
34.00
12.50
6
1
764
S27-LOWELL
Distribution
Unattended
34.00
12.50
3
1
765
H28-LYNDON
Distribution
Unattended
34.00
12.50
6
1
766
D89-LYONS
Distribution
Unattended
34.00
4.00
5
1
767
S35-MANVILLE
Distribution
Unattended
34.00
12.50
3
1
768
G128-MARKHAM-1
Distribution
Unattended
34.00
12.50
6
1
769
G128-MARKHAM-2
Distribution
Unattended
34.00
4.00
3
1
770
D216-MAYWOOD
Distribution
Unattended
34.00
4.00
6
1
771
S67-MAZON
Distribution
Unattended
34.00
12.50
3
1
772
W216-MEADOWDALE
Distribution
Unattended
34.00
12.50
9
1
773
D201-MELROSE PARK
Distribution
Unattended
34.00
4.00
6
1
774
J38-MESSENGER WOODS
Distribution
Unattended
34.00
12.50
6
1
775
B46-MILLEDGEVILLE
Distribution
Unattended
34.00
12.50
6
1
776
W31-MILTON TWP-1
Distribution
Unattended
34.00
12.50
6
1
777
W31-MILTON TWP-2
Distribution
Unattended
34.00
4.00
3
1
778
S39-MINONK
Distribution
Unattended
34.00
12.50
9
1
779
J20-MISSISSIPPI
Distribution
Unattended
34.00
12.50
9
1
780
B25-MONROE CENTER
Distribution
Unattended
34.00
12.00
9
1
781
H29-MORRISON
Distribution
Unattended
34.00
4.00
4
1
782
C6-MORTON GROVE
Distribution
Unattended
34.00
4.00
6
1
783
C52-MORTON GROVE
Distribution
Unattended
34.00
4.00
5
1
784
C78-MORTON GROVE
Distribution
Unattended
34.00
4.00
6
2
785
C26-MT PROSPECT
Distribution
Unattended
34.00
4.00
6
2
786
A35-MUNDELEIN
Distribution
Unattended
34.00
4.00
3
1
787
W46-NAPERVILLE
Distribution
Unattended
34.00
12.50
6
1
788
J60-NEW LENOX
Distribution
Unattended
34.00
12.50
6
1
789
R14-NORTH
Distribution
Unattended
12.50
4.00
5
1
790
B96-NORTH HAMPSHIRE
Distribution
Unattended
34.00
12.50
9
1
791
C85-NORTHBROOK-1
Distribution
Unattended
34.00
4.00
6
1
792
D51-NORTHLAKE
Distribution
Unattended
34.00
4.00
3
1
793
K50-NORTH MOMENCE
Distribution
Unattended
34.00
12.50
9
1
794
G39-OAK LAWN
Distribution
Unattended
34.00
4.00
5
1
795
G66-OAK LAWN
Distribution
Unattended
34.00
4.00
6
1
796
G125-OAK LAWN
Distribution
Unattended
34.00
4.00
6
1
797
D204-OAK PARK
Distribution
Unattended
12.50
4.00
6
1
798
D292-OAK PARK
Distribution
Unattended
12.50
4.00
6
1
799
H44-OHIO
Distribution
Unattended
34.00
12.50
3
1
800
C21-OPTIMA
Distribution
Unattended
34.00
12.50
9
1
801
G99-PALOS HEIGHTS
Distribution
Unattended
34.00
12.50
6
1
802
F29-PARK FOREST
Distribution
Unattended
34.00
4.00
3
1
803
F41-PARK FOREST
Distribution
Unattended
34.00
4.00
3
1
804
F111-PARK FOREST
Distribution
Unattended
34.00
4.00
5
1
805
C36-PARK RIDGE
Distribution
Unattended
34.00
4.00
6
1
806
C87-PARK RIDGE
Distribution
Unattended
34.00
4.00
3
1
807
C85-NORTHBROOK-2
Distribution
Unattended
34.00
12.50
3
1
808
C97-PARK RIDGE
Distribution
Unattended
34.00
12.50
9
1
809
H59-PAW PAW
Distribution
Unattended
34.00
12.50
3
1
810
B42-PEARL CITY
Distribution
Unattended
34.00
12.50
5
1
811
H66-PLANO
Distribution
Unattended
34.00
12.50
9
1
812
H10-PRARIEVILLE
Distribution
Unattended
34.00
12.50
8
1
813
H91-PROPHETSTOWN
Distribution
Unattended
34.00
12.50
8
1
814
S12-RANSOM
Distribution
Unattended
34.00
12.50
8
1
815
B48-RINK
Distribution
Unattended
34.00
12.50
6
1
816
D143-RIVER FOREST
Distribution
Unattended
12.50
4.00
6
1
817
G31-RIVERDALE
Distribution
Unattended
34.00
4.00
3
1
818
D103-RIVERSIDE
Distribution
Unattended
12.50
4.00
6
1
819
D241-RIVERSIDE
Distribution
Unattended
34.00
4.00
6
1
820
133-ROCK FALLS-2
Distribution
Unattended
34.00
12.50
9
1
821
H41-ROCK FALLS
Distribution
Unattended
34.00
12.50
9
1
822
R18-ROCKTON AVE
Distribution
Unattended
12.50
4.00
5
1
823
A37-ROUND LAKE BEACH
Distribution
Unattended
34.00
12.50
9
1
824
S11-ROWE
Distribution
Unattended
34.00
12.50
2
1
825
S20-RUTLAND
Distribution
Unattended
34.00
12.50
9
1
826
J23-SARATOGA
Distribution
Unattended
34.00
12.50
9
1
827
J65-SENECA
Distribution
Unattended
34.00
12.50
6
1
828
H56-SHABBONA
Distribution
Unattended
34.00
12.50
3
1
829
E38-SILVER LAKE
Distribution
Unattended
34.00
12.50
6
1
830
C28-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
831
C32-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
832
C69-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
833
C74-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
834
C86-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
835
C90-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
836
C94-SKOKIE
Distribution
Unattended
34.00
4.00
6
1
837
H76-SOUTH DIXON
Distribution
Unattended
34.00
12.50
9
1
838
S47-SOUTH WILMINGTON
Distribution
Unattended
34.00
12.50
9
1
839
E10-SOUTH HUNTLEY
Distribution
Unattended
34.00
12.50
9
1
840
K45-ST.ANNE
Distribution
Unattended
34.00
12.50
6
1
841
K52-ST.GEORGE
Distribution
Unattended
34.00
12.50
9
1
842
F132-STEGER
Distribution
Unattended
34.00
4.00
3
1
843
H18-STERLING
Distribution
Unattended
34.00
12.50
5
1
844
312-STEWARD
Distribution
Unattended
34.00
12.50
3
1
845
D114-STICKNEY
Distribution
Unattended
34.00
12.50
6
1
846
D244-STICKNEY TWP
Distribution
Unattended
34.00
12.50
9
1
847
B27-STILLMAN VALLEY
Distribution
Unattended
34.00
12.50
6
1
848
B43-STOCKTON
Distribution
Unattended
34.00
12.50
6
1
849
D194-STONE PARK
Distribution
Unattended
34.00
4.00
6
1
850
R21-SUNSET
Distribution
Unattended
12.50
4.00
5
1
851
W28-SUNSET PARK
Distribution
Unattended
34.00
12.50
6
1
852
F115-THORNTON
Distribution
Unattended
34.00
4.00
3
1
853
G 19 TINLEY PARK
Distribution
Unattended
34.00
12.50
6
1
854
S15-TOLUCA
Distribution
Unattended
34.00
12.50
6
1
855
S19-TONICA
Distribution
Unattended
34.00
12.00
9
1
856
W64-TRI STATE-1
Distribution
Unattended
34.00
12.50
6
1
857
W64-TRI STATE-2
Distribution
Unattended
34.00
4.00
3
1
858
B57-UNION
Distribution
Unattended
34.00
12.50
9
1
859
S36-VERONA
Distribution
Unattended
34.00
12.50
3
1
860
W333-VILLA PARK
Distribution
Unattended
34.00
4.00
6
1
861
A27-WADSWORTH-1
Distribution
Unattended
34.00
12.50
6
1
862
A27-WADSWORTH-2
Distribution
Unattended
34.00
4.00
3
1
863
H40-WALNUT
Distribution
Unattended
34.00
12.50
6
1
864
K15-WARNER BRIDGE
Distribution
Unattended
34.00
12.50
6
1
865
A92-WARREN
Distribution
Unattended
34.00
4.00
1
1
866
B44-WARREN
Distribution
Unattended
34.00
12.50
8
1
867
J33-WASH ST (JOLIET)
Distribution
Unattended
34.00
12.50
9
1
868
H54-WATERMAN
Distribution
Unattended
34.00
12.50
6
1
869
H55-WATERMAN
Distribution
Unattended
34.00
4.00
2
1
870
E41-WAUCONDA
Distribution
Unattended
34.00
4.00
3
1
871
A49-WAUKEGAN
Distribution
Unattended
34.00
4.00
3
1
872
A56-WAUKEGAN
Distribution
Unattended
34.00
4.00
6
1
873
A61-WAUKEGAN-1
Distribution
Unattended
34.00
12.50
6
1
874
A61-WAUKEGAN-2
Distribution
Unattended
34.00
4.00
3
1
875
A63-WAUKEGAN
Distribution
Unattended
34.00
4.00
5
1
876
A65-WAUKEGAN
Distribution
Unattended
34.00
4.00
3
1
877
J13-WAUPONSEE
Distribution
Unattended
34.00
12.50
6
1
878
S16-WENONA-1
Distribution
Unattended
34.00
12.50
3
1
879
S16-WENONA-2
Distribution
Unattended
34.00
4.00
2
1
880
R22-WEST
Distribution
Unattended
12.50
4.00
5
1
881
W335-WEST CHICAGO-1
Distribution
Unattended
34.00
12.50
6
1
882
W335-WEST CHICAGO-2
Distribution
Unattended
34.00
4.00
3
1
883
W17-WEST SUGAR GROVE
Distribution
Unattended
34.00
12.50
9
1
884
D24-WESTERN SPRINGS
Distribution
Unattended
34.00
4.00
9
1
885
W340-WEISBROOK
Distribution
Unattended
34.00
12.50
9
1
886
W304-WHEATON
Distribution
Unattended
34.00
12.50
9
1
887
C31-WILMETTE
Distribution
Unattended
34.00
4.00
5
1
888
C56-WILMETTE
Distribution
Unattended
34.00
4.00
6
1
889
C89-WILMETTE
Distribution
Unattended
34.00
4.00
6
1
890
149-WILMINGTON
Distribution
Unattended
34.00
12.50
9
1
891
D17-WINSTON PARK
Distribution
Unattended
34.00
12.50
9
1
892
G121-WORTH
Distribution
Unattended
34.00
12.50
9
1
893
W354-YORK CENTER
Distribution
Unattended
34.00
12.50
7
1
894
H36-YORKTOWN
Distribution
Unattended
34.00
12.50
6
1
895
W12-YORKVILLE
Distribution
Unattended
34.00
4.00
9
1
896
J29-GORE ROAD
Distribution
Unattended
34.00
12.00
9
1
897
J45 - PINE BLUFF
Distribution
Unattended
34.00
12.50
9
1
898
J40 - WESTERN AVE - 2
Distribution
Unattended
34.00
12.50
18
2
899
A15-ZION
Distribution
Unattended
34.00
12.50
6
1
900
SPARE TRANSFORMER-1
765.00
345.00
34.00
666
4
901
SPARE TRANSFORMER-2
345.00
138.00
34.00
2352
7
902
SPARE TRANSFORMER-3
138.00
69.00
180
3
903
SPARE TRANSFORMER-4
138.00
69.00
12.50
467
7
904
SPARE TRANSFORMER-5
138.00
34.50
137
2
905
SPARE TRANSFORMER-6
138.00
34.50
13.20
653
11
906
SPARE TRANSFORMER-7
138.00
13.20
1990
38
907
SPARE TRANSFORMER-8
69.00
12.50
266
7
908
SPARE TRANSFORMER-9
34.00
13.20
229
36
909
SPARE TRANSFORMER-10
34.00
4.16
183
27
910
SPARE TRANSFORMER-11
12.50
4.16
192
41


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
  1. Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) companies.
  2. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not attempt to include or aggregate amounts in a nonspecific category such as "general".
  3. Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote.
Line No.
Description of the Good or Service
(a)
Name of Associated/Affiliated Company
(b)
Account(s) Charged or Credited
(c)
Amount Charged or Credited
(d)
1
Non-power Goods or Services Provided by Affiliated
2
Information Technology
Baltimore Gas & Electric
648,560
3
Other
Baltimore Gas & Electric
21,765
4
Information Technology
Pepco Holdings LLC
209,858
5
Materials
Pepco Holdings LLC
2,747
6
Transmission Services
ComEd of Indiana
5,271,201
7
Materials
PECO Energy Company
613,569
8
Information Technology
PECO Energy Company
165,344
9
Financial Services - Direct
(a)
Exelon BSC
5,165,029
10
Communications Services - Direct
Exelon BSC
321,029
11
Human Resources - Direct
Exelon BSC
22,685,092
12
Legal Governance - Direct
Exelon BSC
2,822,568
13
Executive Services - Direct
Exelon BSC
69,062
14
Utility Services - Direct
Exelon BSC
1,442,251
15
Real Estate Services - Direct
Exelon BSC
131,809
16
Supply Services - Direct
Exelon BSC
190,603
17
Information Technology - Direct
Exelon BSC
117,742,571
18
Legal Services - Direct
Exelon BSC
1,131,606
19
Financial Services - Indirect
Exelon BSC
46,996,479
20
Communications Services - Indirect
Exelon BSC
8,333,204
21
Human Resources - Indirect
Exelon BSC
2,235,103
22
Legal Governance  - Indirect
Exelon BSC
19,065,213
23
Executive Services - Indirect
Exelon BSC
24,559,915
24
Operations Services - Indirect
Exelon BSC
792,906
25
Real Estate Services - Indirect
Exelon BSC
3,315,447
26
Security Services - Indirect
Exelon BSC
11,476,584
27
Utilities Services - Indirect
Exelon BSC
34,941,206
28
Supply Services - Indirect
Exelon BSC
15,340,441
29
Information Technology - Indirect
Exelon BSC
330,289,342
30
Regulatory Governmental Affairs - Indirect
Exelon BSC
3,248,520
31
BSC Other - Indirect
Exelon BSC
24,648,881
19
20
Non-power Goods or Services Provided for Affiliated
21
Real Estate & Facilities
Exelon BSC
7,062,259
22
Fleet Maintenance
Exelon BSC
2,962
23
Other
Exelon BSC
967,290
24
Construction, O&M & Admin Fees
ComEd of Indiana
792,254
25
Information Technology
Baltimore Gas & Electric
25,585
26
Legal Department Services
Baltimore Gas & Electric
53,403
27
Audit Services
Baltimore Gas & Electric
724
28
Transmission Services
Baltimore Gas & Electric
76,564
29
Information Technology
PECO Energy Company
357,257
30
Legal Department Services
PECO Energy Company
50,880
31
Audit Services
PECO Energy Company
735
32
Materials
PECO Energy Company
29,921
33
Transmission Services
PECO Energy Company
97,414
34
Information Technology
Pepco Holdings LLC
22,369
35
Legal Department Services
Pepco Holdings LLC
75,388
36
Audit Services
Pepco Holdings LLC
1,067
37
Materials
Pepco Holdings LLC
1,432
38
Transmission Services
Pepco Holdings LLC
138,348
42


Name of Respondent:

Commonwealth Edison Company
This report is:

(1)
An Original

(2)
A Resubmission
Date of Report:

12/31/2024
Year/Period of Report

End of:
2024
/
Q4
FOOTNOTE DATA

(a) Concept: NameOfAssociatedAffiliatedCompany
2024 Exelon Business Services Company Service Areas & Cost Assignment Methods
Exelon Business Services Company, LLC (BSC) provides services to the Exelon system of companies. For discussion purposes, BSC is divided into three groups: 1) core shared services, 2) utility focused services, and 3) corporate governance. The following are descriptions of the service areas and the cost assignment methods applied when billing the services.
The discussion below summarizes the cost assignment methods which generally require direct billing of services to the extent possible, then allocation based on cost causative allocation methods of costs that cannot be directly assigned.
1) CORE SHARED SERVICES AREAS
The Core Shared Services Areas provide a variety of shared support and management services for the Exelon system of companies. These shared services include Information Technology, Security, Supply, Legal Services, Human Resources, Transportation and Real Estate.
Information Technology
Energy Delivery Solutions, Projects & Enterprise Solutions. Provides application support to the business units and centrally manages enterprise-wide applications and business unit specific projects.
Cost Assignment:
Costs for information technology applications which are specific to one Client Company are directly charged to the respective Client Company.
Costs for information technology applications which benefit all or more than one Client Company are allocated to the respective Client Companies based on an appropriate cost causative allocation methodology, which varies from project to project.
Cloud and Infrastructure Engineering and Operations. Manages the enterprise IT infrastructure, provides infrastructure services, and ensures a safe and stable operating environment.
Cost Assignment:
Service costs are directly charged to IT Application Portfolios on a unit price basis for services such as mainframe, email, telephone, LAN, etc. IT Application Portfolio costs are directly charged to Client Companies when specific to one Client Company. IT Application Portfolio costs that benefit more than one Client Company are allocated based on an appropriate cost causative allocation methodology.
IT Governance. Comprises an IT Program Management Office and Business Office focused on establishing standard processes, procedures and methods and Enterprise Architecture and Planning responsible for comprehensive enterprise strategic planning and architecture standards and assurance.
Cost Assignment:
Service costs are allocated to Client Companies based on an IT Service Billings ratio of each Client Company or an appropriate cost causative allocation methodology.
Corporate & Information Security Services (CISS)
Includes the costs of providing Corporate and Information Security services for the Client Companies
Corporate Security and Analysis. Provides security policy development and alignment with policies and strategic initiatives; Intelligence gathering and analytical services across the corporation to include threat / risk assessments and recommendations.
Information Security. Develop, maintain and enforce a security strategy, policy and standards framework that aligns Exelon business need, legislative and regulatory requirements, and industry standard practices.
Cost Assignment
Costs for Corporate and Information Security services which are specific to one Client Company are directly charged to the respective Client Company.
Service costs are allocated to Client Companies based on an IT Service Billings ratio of each Client Company or an appropriate cost causative allocation methodology which varies by service.
Supply
Includes the costs of providing services related to the supply function for the Client Companies. Does not include costs of the materials/services purchased under the Purchase Orders/Contracts established by BSC Supply Services group or the purchase or sale of power.
Strategic Sourcing. Manages the sourcing of categories across Exelon, drives total cost of ownership, and manages supplier relationships.
Supply Operations. Provides tactical support to business unit operations. Embedded Supply employees perform these services for the Utilities.
Supply Support. Comprises e-business functions, supply projects, and diversity initiatives, as well as policies, programs, systems and decision support systems.
Cost Assignment:
Whenever possible, service costs are directly charged to Client Companies.
Remaining service costs are allocated to Client Companies based on various expenditure-spend methodologies (generally, the services and/or materials purchased by each Client Company).
Accounts Payable. Processes invoices and administers the P-Card (purchasing-card) program.
Cost Assignment:
Accounts payable service costs are directly charged to Client Companies on a unit price based on transactions processed for each Client Company.
Legal Services
Corporate & Commercial. Provides legal support for commercial contract negotiations, acquisitions, intellectual property, strategy, securities, financial reporting, real estate, nuclear related issues, bankruptcy, credit and collections, environmental, general corporate, and other transactional matters.
Environmental . Provides legal support for the defense of agency enforcement actions, compliance counseling, environmental matters relevant to permitting and re-licensing of generation facilities, support for safety and OSHA compliance, EHS compliance audits and NRC investigations.
Labor & Employment. Represents Exelon’s Client Companies in a wide range of employment related matters before agencies, arbitrators, and state and federal courts; provides advice and counsel on all labor and employment related matters.
Litigation. Provides legal support for all forms of disputes, including breach of contract, commercial disputes, personal injury, and property damage.
Regulatory. Represents Exelon’s Client Companies before various regulatory agencies, including the Illinois Commerce Commission, the Pennsylvania Public Utility Commission, Maryland Public Service Commission, New Jersey Board of Public Utilities, Delaware Public Service Commission, Public Service Commission of the District of Columbia and the Federal Energy Regulatory Commission.
Client Services. Comprised of the business functions of the Legal Department, including financial management, client billing, business planning and analysis, human resources, systems management, and general administration.
Cost Assignment:
Costs for lawyers and paralegals are directly charged to Client Companies when possible.
The remaining services are allocated on the Modified Massachusetts Formula, an average of each Client Company’s Gross Revenues, Total Assets and Direct Labor to the totals of all Client Companies.
Human Resources
Human Resources is divided into two groups - (i) General HR activities, including support functions such as diversity, planning and development, employee health and benefits, compensation planning, management and employee development; HR planning, technology and metrics for HR field units; worker’s compensation administration; benefits administration services; payroll processing; HR Solutions Hub, HR/Payroll system maintenance and HR process improvement support and metric reporting; (ii) Labor Relations, including development and management of labor relations strategy in support of business units with represented employees.
Cost Assignment:
Whenever possible, service costs are directly charged to Client Companies.
Most general Human Resources Activities costs are directly charged to Client Companies on a unit price basis based on the total employee headcount of each Client Company. Payroll processing costs are directly charged to Client Companies on a unit price based on paycheck counts of each Client Company.
Labor Relations costs are directly charged to Client Companies on a unit price basis based on the headcount of represented employees of each Client Company or direct charged based on time and materials.
Transportation
Transportation. Coordinates corporate aircraft services.
Cost Assignment:
Service costs are directly charged to Client Companies on a unit price based on total occupied flight hours of each Client Company.
Secure Executive Transportation. Ground transportation for executives.
Cost Assignment:
Whenever possible, service costs are directly charged to specific utility companies.
The remaining service costs that cannot be directly charged are allocated to the Utilities based on the Modified Massachusetts Formula, an average of each utility's Gross Revenues, Total Assets and Direct Labor to the total of all Client Companies.
Real Estate
Includes real estate portfolio and asset management strategy, lease administration for facilities, land or infrastructure obligations, property management, mail services and other real estate consulting services, generally concentrating on non-utility and non-power plant operations.
Cost Assignment for the above mentioned area:
Service costs are allocated to Client Companies based on occupied square footage.
2) EXELON UTILITIES AREA
Exelon Utilities is comprised of a small utility-focused corporate governance and oversight function that will facilitate collaboration among the utilities to achieve the highest standards of organizational effectiveness, operational excellence, and customer and stakeholder satisfaction.
Utility Strategy & Policy includes utility-wide strategy formulation and implementation, regulatory policy/issue alignment and implementation, utility investment and business model strategy and scenario analysis and analytical support to the utilities.
Utility Oversight includes governance and oversight of a Peer Group structure that aligns across the client utilities to drive consistency, best practices and innovation in the core functions of the Management Model; tracks performance regarding key performance indicators, improvement initiatives and industry standards; analyzes opportunities and develops recommendations on issues pertinent to leadership; coordinate of the business planning process and provides oversight of Management Model documentation integration across the Utilities.
Cost Assignment for the above mentioned groups:
Whenever possible, service costs are directly charged to specific utility companies.
The remaining Utility Oversight costs that cannot be directly charged are allocated to the Utilities based on a utility variation of the Modified Massachusetts Formula, an average of each utility’s Gross Revenues, Total Assets and Direct Labor to the totals of all utility companies.
Transmission Strategy & Compliance manages the Exelon Utilities’ interface with the applicable regional transmission and reliability organizations, oversees the implementation of FERC Regulations, NERC Reliability Standards and EU Physical CISS Programs to ensure ongoing compliance, represents utilities’ interests and implements corporate strategy in both PJM Regional Transmission Organization and Regional Reliability Organization stakeholder proceedings, and also provides market intelligence and analytic support to strategic transmission studies and other initiatives as needed.
Cost Assignment:
Whenever possible, service costs are directly charged to specific utility companies.
Remaining service costs that benefit participating utilities are allocated for transmission related activities based on transmission peak load allocation.
Transmission System Operations Operate, control, and monitor Exelon transmission systems. Perform Transmission Owner Scheduling, System Control, and Dispatch Service functions per PJM Open Access Transmission Tariff Schedule 1A and fulfill all associated PJM Operating Agreement and PJM Manual obligations of local transmission control center for Exelon.
Cost Assignment:
Whenever possible, service costs are directly charged to specific utility companies.
Remaining service costs that benefit participating utilities are allocated for transmission related activities based on transmission peak load allocation.
Corporate Physical Security Services. Includes corporate security functions such as security investigations and assessments, crisis management response, and security related training.
Cost Assignment:
Costs for Corporate Physical Security services which are specific to one Client Company are directly charged to the respective Client Company.
The remaining physical security costs are allocated on the Modified Massachusetts Formula, an average of each Client Company's Gross Revenues, Total Assets, and Direct Labor to the totals of all Client Companies.
3) CORPORATE GOVERNANCE AREAS
The Corporate Governance Areas house employees who provide corporate governance services for the Exelon system of companies. The Corporate Governance Areas in BSC include:
Finance. Includes Senior Executive Vice President and CFO Exelon, Finance, Treasury (cash management services), Controller, External Audit fees, Tax (consolidated Federal and state returns), Financial Planning and Analysis, Investor Relations, Capital Markets, Insurance Services, and External Reporting.
Compliance, Audit and Risk Services. Includes three separate but complementary teams: Compliance & Ethics, Enterprise Risk Management, Exelon Audit Services (Sarbanes Oxley compliance)
Executives and General Activities . Includes Exelon senior leadership positions including President and Chief Executive Officer and other Executive Committee members. Also includes general activities, such as income and other taxes, severance and interest, and Board of Directors costs and shareholder meetings.
Communications, Public Advocacy and Corporate Relations. Includes Exelon Corporation advertising/brand management, donations/contributions, sponsorships and annual report creation, shareholder/investor external communications, and other communication services; as well as Client Company public advocacy, advertising, coordination of donations/contribution approval, corporate/media relations, and corporate and external communications; public affairs activities; internal communications; and photography, videography and video production services. Embedded Communication employees also perform these services for the Utilities
Governmental and Regulatory Affairs and Public Policy . Includes executive oversight; management services for compliance with Federal laws, regulations and other policy requirements including relationship management with Congress, Administration and regulators; strategy development and
lobbying and advocacy related to Federal legislative and regulatory initiatives; competition initiative activities; PAC administration and operation; grassroots activities; and Federal public affairs activities.
Legal Governance. Includes General Counsel and the Corporate Governance group (including the corporation’s compliance and ethics program and Corporate Secretary and shareholder services).
Corporate Development. Includes strategic expertise and governance in the evaluation and execution of merger and acquisition opportunities, evaluating company assets for divestiture opportunities, and providing financial and transactional support to restructuring projects.
Corporate Strategy, Innovation & Sustainability. Provides strategic support for senior leadership; program leadership for Exelon's sustainable growth strategy; and corporate-wide governance, oversight, and support for innovation, environment, and safety functions.
Investments. Includes determining the investment strategy and asset allocation of Exelon’s pension funds, VEBA post retirement funds, managing relationships with investment managers, overseeing daily investment activities and maintaining a well-diversified investment menu for the Employee Savings Plans. (Certain Investments Area costs are reimbursable by and therefore billed directly to the applicable funds and plans).
Cost Assignment for the Corporate Governance Areas:
Whenever possible, service costs are directly charged to Client Companies.
The remaining corporate governance costs that cannot be directly charged are allocated to Client Companies based on the Modified Massachusetts Formula, an average of each Client Company’s Gross Revenues, Total Assets and Direct Labor to the totals of all Client Companies.
(b) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
BSC - IT Direct Billing by FERC ACCT:
FERC
107000 $ 49,064,656 
107998 (31,000)
108100 1,382,294 
416000 1,711 
557000 988,078 
560000 (18,738)
561700 4,846 
566000 887,956 
568000 (25,371)
569100 445,715 
569200 747,989 
569300 2,119,695 
570000 560 
571000 791 
580000 (85,089)
582000 584 
586000 (514,878)
588000 25,277,164 
590000 (186,550)
592000 3,524 
593000 60,528 
598000 2,181,197 
903000 9,683,201 
908000 5,066,010 
923000 19,351,904 
930200 22,949 
935000 1,261,381 
920995 131 
184000 51,333 
Total $ 117,742,571 
(c) Concept: AccountsChargedOrCreditedTransactionsWithAssociatedAffiliatedCompanies
BSC - IT Indirect Billing by FERC ACCT:
FERC
107000 $ 175,039,383 
107998 (275,000)
108100 1,957,089 
426100 4,198 
426500 164,191 
560000 (48,804)
566000 8,428,834 
568000 (36,072)
569100 9,529 
569200 255,043 
569300 (938,666)
570000 692 
571000 1,043 
580000 (120,980)
582000 788 
586000 418,075 
588000 22,729,479 
590000 (265,238)
592000 4,825 
598000 6,154,827 
903000 38,944,617 
908000 8,405,879 
920995 162 
923000 69,450,988 
930100 34 
935000 4,426 
Total $ 330,289,342 
XBRL Instance File
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